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, 2016~~March 31, 2017.

___ 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 or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated ~~filer”~~filer,” “smaller reporting company” and ~~“smaller reporting~~“emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer X Accelerated filer __ Non-accelerated filer __

Smaller reporting company__ Emerging growth company__

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.__

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~~April 24, ~~2016,~~2017, the Company had ~~210,521,971~~210,909,327 shares of common stock outstanding.

Table of Contents

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ONEOK, Inc.

TABLE OF CONTENTS



Part I.	Financial Information	Page No.
Item 1.	Financial Statements (Unaudited)	6
	Consolidated Statements of Income - Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~	6
	Consolidated Statements of Comprehensive Income - Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~	7
	Consolidated Balance Sheets - ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015~~2016	8
	Consolidated Statements of Cash Flows - ~~Nine~~Three Months Ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~	11
	Consolidated Statements of Changes in Equity - ~~Nine~~Three Months Ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~	12
	Notes to Consolidated Financial Statements	14
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3734
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	6053
Item 4.	Controls and Procedures	6255
Part II.	Other Information	6255
Item 1.	Legal Proceedings	6255
Item 1A.	Risk Factors	6355
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6356
Item 3.	Defaults Upon Senior Securities	6356
Item 4.	Mine Safety Disclosures	6356
Item 5.	Other Information	6356
Item 6.	Exhibits	6356
Signature		6558

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.

GLOSSARY

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



2017 Credit Agreement	ONEOK’s $2.5 billion revolving credit agreement effective upon the closing of the Merger Transaction and the terminations of the ONEOK Credit Agreement and ONEOK Partners Credit Agreement
AFUDC	Allowance for funds used during construction
Annual Report	Annual Report on Form 10-K for the year ended December 31, ~~2015~~2016
ASU	Accounting Standards Update
Bbl	Barrels, 1 barrel is equivalent to 42 United States gallons
BBtu/d	Billion British thermal units per day
Bcf	Billion cubic feet
Bcf/d	Billion cubic feet per day
CFTC	U.S. Commodity Futures Trading Commission
Clean Air Act	Federal Clean Air Act, as amended
EBITDA	Earnings before interest expense, income taxes, depreciation and amortization
EPA	United States Environmental Protection Agency
Exchange Act	Securities Exchange Act of 1934, as amended
~~FASB~~	~~Financial Accounting Standards Board~~
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the United States of America
GHG	Greenhouse gas
Intermediate Partnership	ONEOK Partners Intermediate Limited Partnership, a wholly owned subsidiary of ONEOK Partners, L.P.
LIBOR	London Interbank Offered Rate
MBbl/d	Thousand barrels per day
MDth/d	Thousand dekatherms per day
Merger Agreement	Agreement and Plan of Merger, dated as of January 31, 2017, by and among ONEOK, Merger Sub, ONEOK Partners and ONEOK Partners GP
Merger Sub	New Holdings Subsidiary, LLC, a wholly owned subsidiary of ONEOK
Merger Transaction	The transaction contemplated by the Merger Agreement pursuant to which ONEOK will acquire all of ONEOK Partners’ outstanding common units representing limited partner interests in ONEOK Partners not already directly or indirectly owned by ONEOK
MMBbl	Million barrels
MMBtu	Million British thermal units
MMcf/d	Million cubic feet per day
Moody’s	Moody’s Investors Service, Inc.
NGL(s)	Natural gas liquid(s)
NGL products	Marketable natural gas liquid purity products, such as ethane, ethane/propane mix, propane, iso-butane, normal butane and natural gasoline
NYMEX	New York Mercantile Exchange
NYSE	New York Stock Exchange
ONEOK	ONEOK, Inc.
ONEOK Credit Agreement	ONEOK’s $300 million amended and restated revolving credit agreement effective as of January 31, 2014
ONEOK Partners	ONEOK Partners, L.P.
ONEOK Partners Credit Agreement	ONEOK Partners’ $2.4 billion amended and restated revolving credit agreement effective as of January 31, 2014, as amended
ONEOK Partners GP	ONEOK Partners GP, L.L.C., a wholly owned subsidiary of ONEOK and the sole general partner of ONEOK Partners
OPIS	Oil Price Information Service
Partnership Agreement	Third Amended and Restated Agreement of Limited Partnership of ONEOK Partners, L.P., as amended



PHMSA	United States Department of Transportation Pipeline and Hazardous Materials Safety Administration
POP	Percent of Proceeds
Quarterly Report(s)	Quarterly Report(s) on Form 10-Q
Roadrunner	Roadrunner Gas Transmission, LLC, a ONEOK Partners 50 percent owned joint venture
S&P	S&P Global Ratings
SCOOP	South Central Oklahoma Oil Province, an area in the Anadarko Basin in Oklahoma
SEC	Securities and Exchange Commission
STACK	Sooner Trend Anadarko Canadian Kingfisher, an area in the Anadarko Basin in Oklahoma
Term Loan Agreement	ONEOK Partners’ senior unsecured delayed-draw three-year $1.0 billion term loan agreement dated January 8, 2016,


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

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS


ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
(Unaudited)	2016			2015			2016			2015			2017			2016
	(Thousands of dollars, except per share amounts)												(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	1,840,523		$	1,484,350		$	4,757,306		$	4,642,320		$	2,216,717		$	1,283,511
Services	517,384			414,596			1,509,167			1,189,984			532,894			490,948
Total revenues	2,357,907			1,898,946			6,266,473			5,832,304			2,749,611			1,774,459
Cost of sales and fuel (exclusive of items shown separately below)	1,751,593			1,360,809			4,474,654			4,307,766			2,143,843			1,195,738
Operations and maintenance	165,664			146,979			488,476			442,179			164,769			155,145
Depreciation and amortization	98,550			88,299			292,275			261,241			99,419			94,478
General taxes	18,487			17,198			64,529			66,366			27,153			21,870
(Gain) loss on sale of assets	(5,744		)	726			(9,537		)	610			7			(4,206		)
Operating income	329,357			284,935			956,076			754,142			314,420			311,434
Equity in net earnings from investments (Note J)	35,155			32,244			100,441			93,205			39,564			32,914
Allowance for equity funds used during construction	—			177			208			1,718			13			208
Other income	4,242			71			9,351			249			4,341			305
Other expense	(710		)	(7,508		)	(2,288		)	(7,754		)	(750		)	(637		)
Interest expense (net of capitalized interest of $3,806, $8,851, $9,265 and $26,008, respectively)	(118,240		)	(106,923		)	(355,463		)	(306,057		)
Interest expense (net of capitalized interest of $1,441 and 2,887, respectively)													(116,462		)	(118,247		)
Income before income taxes	249,804			202,996			708,325			535,503			241,126			225,977
Income taxes	(55,012		)	(38,298		)	(157,536		)	(123,948		)	(54,941		)	(50,066		)
Income from continuing operations	194,792			164,698			550,789			411,555			186,185			175,911
Income (loss) from discontinued operations, net of tax (Note M)	(576		)	(3,860		)	(1,755		)	(4,144		)
Income (loss) from discontinued operations, net of tax													—			(952		)
Net income	194,216			160,838			549,034			407,411			186,185			174,959
Less: Net income attributable to noncontrolling interests	102,072			78,681			287,500			187,949			98,824			91,513
Net income attributable to ONEOK	$	92,144		$	82,157		$	261,534		$	219,462		$	87,361		$	83,446
Amounts attributable to ONEOK:
Income from continuing operations	$	92,720		$	86,017		$	263,289		$	223,606		$	87,361		$	84,398
Income (loss) from discontinued operations	(576		)	(3,860		)	(1,755		)	(4,144		)	—			(952		)
Net income	$	92,144		$	82,157		$	261,534		$	219,462		$	87,361		$	83,446
Basic earnings per share:
Income from continuing operations (Note H)	$	0.44		$	0.41		$	1.25		$	1.06		$	0.41		$	0.40
Income (loss) from discontinued operations	—			(0.02		)	(0.01		)	(0.02		)	—			—
Net income	$	0.44		$	0.39		$	1.24		$	1.04		$	0.41		$	0.40
Diluted earnings per share:
Income from continuing operations (Note H)	$	0.44		$	0.41		$	1.24		$	1.06		$	0.41		$	0.40
Income (loss) from discontinued operations	(0.01		)	(0.02		)	(0.01		)	(0.02		)	—			—
Net income	$	0.43		$	0.39		$	1.23		$	1.04		$	0.41		$	0.40
Average shares (thousands)
Basic	211,309			210,296			211,038			210,138			211,619			210,781
Diluted	212,870			210,524			212,123			210,509			213,602			211,071
Dividends declared per share of common stock	$	0.615		$	0.605		$	1.845		$	1.815		$	0.615		$	0.615

See accompanying Notes to Consolidated Financial Statements.


ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME	CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended						Nine Months Ended							Three Months Ended
	September 30,						September 30,							March 31,
(Unaudited)	2016			2015			2016			2015				2017		2016
	(Thousands of dollars)												(Thousands of dollars)
Net income	$	194,216		$	160,838		$	549,034		$	407,411			$	186,185	$	174,959
Other comprehensive income (loss), net of tax
Unrealized gains (losses) on derivatives, net of tax of $(1,301), $(1,109), $15,033 and $(2,156), respectively	7,237			14,840			(83,580		)	19,217
Realized (gains) losses on derivatives in net income, net of tax of $(811), $2,957, $1,658 and $5,621, respectively	3,083			(15,259		)	(13,496		)	(35,530		)
Unrealized holding gains (losses) on available-for-sale securities, net of tax of $0, $0, $0 and $648, respectively	—			—			—			(955		)
Change in pension and postretirement benefit plan liability, net of tax of $(1,035), $(1,599), $(3,105) and $(4,798), respectively	1,553			2,441			4,658			7,320
Other comprehensive income (loss) on investments in unconsolidated affiliates, net of tax of $108, $0, $1,840 and $0, respectively	(600		)	—			(10,231		)	—
Unrealized gains (losses) on derivatives, net of tax of $(4,401) and $3,039, respectively														24,456		(16,894		)
Realized (gains) losses on derivatives in net income, net of tax of $(3,365) and $1,276, respectively														17,283		(8,525		)
Change in pension and postretirement benefit plan liability, net of tax of $(1,360) and $(1,035), respectively														2,041		1,553
Other comprehensive income (loss) on investments in unconsolidated affiliates, net of tax of $(58) and $884, respectively														325		(4,917		)
Total other comprehensive income (loss), net of tax	11,273			2,022			(102,649		)	(9,948		)		44,105		(28,783		)
Comprehensive income	205,489			162,860			446,385			397,463				230,290		146,176
Less: Comprehensive income attributable to noncontrolling interests	108,450			81,481			211,960			177,760				127,641		70,102
Comprehensive income attributable to ONEOK	$	97,039		$	81,379		$	234,425		$	219,703			$	102,649	$	76,074

See accompanying Notes to Consolidated Financial Statements.


ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS

	September 30,		December 31,		March 31,		December 31,
(Unaudited)	2016		2015		2017		2016
Assets	(Thousands of dollars)				(Thousands of dollars)
Current assets
Cash and cash equivalents	$	237,410	$	97,619	$	310,808	$	248,875
Accounts receivable, net	737,224		593,979		734,844		872,430
Materials and supplies	81,701		76,696
Natural gas and natural gas liquids in storage	217,769		128,084		193,339		140,034
Commodity imbalances	43,770		38,681		30,904		60,896
Other current assets	50,759		39,946		108,552		106,898
Assets of discontinued operations (Note M)	658		205
Assets of discontinued operations					—		551
Total current assets	1,369,291		975,210		1,378,447		1,429,684
Property, plant and equipment
Property, plant and equipment	14,943,225		14,530,460		15,154,360		15,078,497
Accumulated depreciation and amortization	2,416,476		2,156,471		2,600,776		2,507,094
Net property, plant and equipment	12,526,749		12,373,989		12,553,584		12,571,403
Investments and other assets
Investments in unconsolidated affiliates	943,390		948,221		956,388		958,807
Goodwill and intangible assets	1,008,334		1,017,258		1,002,384		1,005,359
Other assets	121,529		112,598		176,755		162,998
Assets of discontinued operations (Note M)	12,742		18,835
Assets of discontinued operations					—		10,500
Total investments and other assets	2,085,995		2,096,912		2,135,527		2,137,664
Total assets	$	15,982,035	$	15,446,111	$	16,067,558	$	16,138,751

See accompanying Notes to Consolidated Financial Statements.


ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	September 30,			December 31,			March 31,			December 31,
(Unaudited)	2016			2015			2017			2016
Liabilities and equity	(Thousands of dollars)						(Thousands of dollars)
Current liabilities							��
Current maturities of long-term debt (Note E)	$	460,650		$	110,650		$	410,650		$	410,650
Short-term borrowings (Note D)	693,500			546,340
Short-term borrowings (Note E)							1,290,729			1,110,277
Accounts payable	711,817			615,982			703,278			874,731
Commodity imbalances	134,658			74,460			114,542			142,646
Accrued interest	104,137			129,043			90,151			112,514
Other current liabilities	214,662			132,556			122,624			166,042
Liabilities of discontinued operations (Note M)	22,540			29,235
Liabilities of discontinued operations							—			19,841
Total current liabilities	2,341,964			1,638,266			2,731,974			2,836,701
Long-term debt, excluding current maturities (Note E)	8,320,144			8,323,582			7,919,826			7,919,996
Deferred credits and other liabilities
Deferred income taxes	1,573,950			1,436,715			1,612,039			1,623,822
Other deferred credits	296,751			264,248			334,206			321,846
Liabilities of discontinued operations (Note M)	9,012			16,964
Liabilities of discontinued operations							—			7,471
Total deferred credits and other liabilities	1,879,713			1,717,927			1,946,245			1,953,139
Commitments and contingencies (Note L)
Equity (Note F)
ONEOK shareholders’ equity:
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 210,517,586 shares at September 30, 2016; issued 245,811,180 shares and outstanding 209,731,028 shares at December 31, 2015	2,458			2,458
Common stock, $0.01 par value: authorized 600,000,000 shares; issued 245,811,180 shares and outstanding 210,906,018 shares at March 31, 2017; issued 245,811,180 shares and outstanding 210,681,661 shares at December 31, 2016							2,458			2,458
Paid-in capital	1,264,041			1,378,444			1,232,069			1,234,314
Accumulated other comprehensive loss (Note G)	(154,351		)	(127,242		)	(139,062		)	(154,350		)
Retained earnings	—			—			30,887			—
Treasury stock, at cost: 35,293,594 shares at September 30, 2016, and 36,080,152 shares at December 31, 2015	(897,852		)	(917,862		)
Treasury stock, at cost: 34,905,162 shares at March 31, 2017, and 35,129,519 shares at December 31, 2016							(887,970		)	(893,677		)
Total ONEOK shareholders’ equity	214,296			335,798			238,382			188,745
Noncontrolling interests in consolidated subsidiaries	3,225,918			3,430,538			3,231,131			3,240,170
Total equity	3,440,214			3,766,336			3,469,513			3,428,915
Total liabilities and equity	$	15,982,035		$	15,446,111		$	16,067,558		$	16,138,751

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Nine Months Ended						Three Months Ended
	September 30,						March 31,
(Unaudited)	2016			2015			2017			2016
	(Thousands of dollars)						(Thousands of dollars)
Operating activities
Net income	$	549,034		$	407,411		$	186,185		$	174,959
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	292,275			261,241			99,419			94,478
Equity in net earnings from investments	(100,441		)	(93,205		)	(39,564		)	(32,914		)
Distributions received from unconsolidated affiliates	106,381			92,042			39,520			34,789
Deferred income taxes	157,819			124,615			53,397			53,725
Share-based compensation expense	31,112			13,732			5,907			8,232
Pension and postretirement benefit expense, net of contributions	8,270			10,145			(5,018		)	3,039
Allowance for equity funds used during construction	(208		)	(1,718		)	(13		)	(208		)
(Gain) loss on sale of assets	(9,537		)	610			7			(4,206		)
Changes in assets and liabilities:
Accounts receivable	(145,430		)	157,742			137,586			68,326
Natural gas and natural gas liquids in storage	(89,685		)	(8,174		)	(53,305		)	(27,991		)
Accounts payable	138,198			(191,542		)	(122,843		)	(64,088		)
Commodity imbalances, net	55,109			25,728			1,888			2,968
Settlement of exit activities liabilities	(16,211		)	(31,207		)	(4,119		)	(6,186		)
Accrued interest	(24,906		)	3,577			(22,363		)	(24,413		)
Risk-management assets and liabilities	(48,695		)	(45,240		)	45,977			(23,813		)
Other assets and liabilities, net	18,943			(30,680		)	(53,571		)	(26,030		)
Cash provided by operating activities	922,028			695,077			269,090			230,667
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(491,528		)	(930,316		)	(112,737		)	(196,411		)
Contributions to unconsolidated affiliates	(55,177		)	(27,540		)	(4,422		)	(158		)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	43,018			25,111			7,400			11,764
Proceeds from sale of assets	19,099			3,171			296			14,858
Other	—			(12,607		)
Cash used in investing activities	(484,588		)	(942,181		)	(109,463		)	(169,947		)
Financing activities
Dividends paid	(388,103		)	(380,498		)	(129,842		)	(129,235		)
Distributions to noncontrolling interests	(412,539		)	(396,847		)	(136,680		)	(137,980		)
Borrowing (repayment) of short-term borrowings, net	147,160			(768,024		)	180,452			(101,773		)
Issuance of long-term debt, net of discounts	1,000,000			1,291,506			—			1,000,000
Debt financing costs	(2,770		)	(17,126		)	—			(2,770		)
Repayment of long-term debt	(656,117		)	(5,795		)	(1,951		)	(652,148		)
Issuance of common stock	14,948			13,839			3,722			3,964
Issuance of common units, net of issuance costs	—			375,660
Cash provided by (used in) financing activities	(297,421		)	112,715
Other							(13,395		)	(1,189		)
Cash used in financing activities							(97,694		)	(21,131		)
Change in cash and cash equivalents	140,019			(134,389		)	61,933			39,589
Change in cash and cash equivalents included in discontinued operations	(228		)	(52		)	—			11
Change in cash and cash equivalents from continuing operations	139,791			(134,441		)	61,933			39,600
Cash and cash equivalents at beginning of period	97,619			172,812			248,875			97,619
Cash and cash equivalents at end of period	$	237,410		$	38,371		$	310,808		$	137,219

See accompanying Notes to Consolidated Financial Statements.


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

	ONEOK Shareholders’ Equity									ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Loss			Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Loss
	(Shares)	(Thousands of dollars)								(Shares)	(Thousands of dollars)
January 1, 2016	245,811,180	$	2,458	$	1,378,444		$	(127,242	)
January 1, 2017										245,811,180	$	2,458	$	1,234,314		$	(154,350	)
Cumulative effect adjustment for adoption of ASU 2016-09										—	—		—			—
Net income	—	—		—			—			—	—		—			—
Other comprehensive income (loss) (Note G)	—	—		—			(27,109		)	—	—		—			15,288
Common stock issued	—	—		(531		)	—			—	—		(2,506		)	—
Common stock dividends - $1.845 per share (Note F)	—	—		(126,569		)	—
Common stock dividends - $0.615 per share (Note F)										—	—		—			—
Distributions to noncontrolling interests	—	—		—			—			—	—		—			—
Other	—	—		12,697			—			—	—		261			—
September 30, 2016	245,811,180	$	2,458	$	1,264,041		$	(154,351	)
March 31, 2017										245,811,180	$	2,458	$	1,232,069		$	(139,062	)


	ONEOK Shareholders’ Equity									ONEOK Shareholders’ Equity
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Loss			Common Stock Issued	Common Stock		Paid-in Capital			Accumulated Other Comprehensive Loss
	(Shares)	(Thousands of dollars)								(Shares)	(Thousands of dollars)
January 1, 2015	245,811,180	$	2,458	$	1,541,583		$	(136,353	)
January 1, 2016										245,811,180	$	2,458	$	1,378,444		$	(127,242	)
Net income	—	—		—			—			—	—		—			—
Other comprehensive income (loss) (Note G)	—	—		—			241
Other comprehensive income (loss)										—	—		—			(7,372		)
Common stock issued	—	—		(6,284		)	—			—	—		(3,679		)	—
Common stock dividends - $1.815 per share (Note F)	—	—		(22,807		)	—
Issuance of common units of ONEOK Partners (Note K)	—	—		(34,446		)	—
Common stock dividends - $0.615 per share (Note F)										—	—		(45,789		)	—
Distributions to noncontrolling interests	—	—		—			—			—	—		—			—
Other	—	—		(415		)	—			—	—		(1,425		)	—
September 30, 2015	245,811,180	$	2,458	$	1,477,631		$	(136,112	)
March 31, 2016										245,811,180	$	2,458	$	1,327,551		$	(134,614	)


ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY	CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY												CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Continued)
	ONEOK Shareholders’ Equity												ONEOK Shareholders’ Equity
(Unaudited)	Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)												(Thousands of dollars)
January 1, 2016	$	—		$	(917,862	)	$	3,430,538		$	3,766,336
January 1, 2017													$	—		$	(893,677	)	$	3,240,170		$	3,428,915
Cumulative effect adjustment for adoption of ASU 2016-09													73,368			—			—			73,368
Net income	261,534			—			287,500			549,034			87,361			—			98,824			186,185
Other comprehensive income (loss) (Note G)	—			—			(75,540		)	(102,649		)	—			—			28,817			44,105
Common stock issued	—			20,010			—			19,479			—			5,707			—			3,201
Common stock dividends - $1.845 per share (Note F)	(261,534		)	—			—			(388,103		)
Common stock dividends - $0.615 per share (Note F)													(129,842		)	—			—			(129,842		)
Distributions to noncontrolling interests	—			—			(412,539		)	(412,539		)	—			—			(136,680		)	(136,680		)
Other	—			—			(4,041		)	8,656			—			—			—			261
September 30, 2016	$	—		$	(897,852	)	$	3,225,918		$	3,440,214
March 31, 2017													$	30,887		$	(887,970	)	$	3,231,131		$	3,469,513


	ONEOK Shareholders’ Equity												ONEOK Shareholders’ Equity
(Unaudited)	Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity			Retained Earnings			Treasury Stock			Noncontrolling Interests in Consolidated Subsidiaries			Total Equity
	(Thousands of dollars)												(Thousands of dollars)
January 1, 2015	$	138,128		$	(953,701	)	$	3,413,768		$	4,005,883
January 1, 2016													$	—		$	(917,862	)	$	3,430,538		$	3,766,336
Net income	219,462			—			187,949			407,411			83,446			—			91,513			174,959
Other comprehensive income (loss) (Note G)	—			—			(10,189		)	(9,948		)
Other comprehensive income (loss)													—			—			(21,411		)	(28,783		)
Common stock issued	—			24,196			—			17,912			—			9,355			—			5,676
Common stock dividends - $1.815 per share (Note F)	(357,691		)	—			—			(380,498		)
Issuance of common units of ONEOK Partners (Note K)	—			—			428,590			394,144
Common stock dividends - $0.615 per share (Note F)													(83,446		)	—			—			(129,235		)
Distributions to noncontrolling interests	—			—			(396,847		)	(396,847		)	—			—			(137,980		)	(137,980		)
Other	101			—			(438		)	(752		)	—			—			(4,041		)	(5,466		)
September 30, 2015	$	—		$	(929,505	)	$	3,622,833		$	4,037,305
March 31, 2016													$	—		$	(908,507	)	$	3,358,619		$	3,645,507

See accompanying Notes to Consolidated Financial Statements.

ONEOK, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


A.	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The ~~2015~~2016 year-end consolidated balance sheet data was derived from our audited financial statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior-year financial statements to conform to the current-year presentation. These unaudited consolidated financial statements should be read in conjunction with our audited consolidated financial statements in our Annual Report.

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

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

~~Consolidation~~Discontinued Operations - ~~Our consolidated~~Beginning in 2017, the results of operations and financial ~~statements include our accounts and the accounts~~position of our ~~subsidiaries over which we have control or~~former energy services business are ~~the primary beneficiary. Management’s judgment is required when:~~

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

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

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

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

~~We record noncontrolling interests~~no longer reflected as discontinued operations in ~~consolidated subsidiaries on~~ our Consolidated ~~Balance Sheets~~Financial Statements and Notes to ~~recognize~~ the ~~portion of ONEOK Partners that we do~~Consolidated Financial Statements, as they are not own. We reflect our ownership interest in ONEOK Partners’ accumulated other comprehensive income (loss) in our consolidated accumulated other comprehensive income (loss). The remaining portion is reflected as an adjustment to noncontrolling interests in consolidated subsidiaries.

~~Goodwill Impairment Test~~material. - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. As the commodity price environment has remained relatively unchanged since 2015, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates. Our goodwill impairment analysis performed as of July 1, 2016, did not result in an impairment charge nor did our analysis reflect any reporting units at risk. In each reporting unit, the fair value substantially exceeded the carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of our reporting units is less than the carrying value of its net assets.

Recently Issued Accounting Standards Update - Changes to GAAP are established by the Financial Accounting Standards Board (FASB) in the form of ASUs to the FASB Accounting Standards Codification. We consider the applicability and impact of all ASUs. ASUs not listed below were assessed and determined to be either not applicable or clarifications of ASUs listed below. The following tables provide a brief description of recent accounting pronouncements and our analysis of the effects on our financial statements:



Standard	Description	Date of Adoption	Effect on the Financial Statements or Other Significant Matters
Standards that were adopted
~~ASU 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments”~~	The standard requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined.	~~First quarter 2016~~	~~There was no impact, but it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments.~~
~~ASU 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent)”~~	The standard removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes the requirement to make certain disclosures for all investments that are eligible to be measured at fair value using the net asset value per share practical expedient.	~~First quarter 2016~~	~~The impact of adopting this standard was not material.~~
~~ASU 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement”~~	The standard clarifies whether a cloud computing arrangement includes a software license. If it does, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses; if not, the customer should account for the arrangement as a service contract.	~~First quarter 2016~~	~~The impact of adopting this standard was not material.~~
~~ASU 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis”~~	The standard eliminates the presumption that a general partner should consolidate a limited partnership. It also modifies the evaluation of whether limited partnerships are variable interest entities or voting interest entities and adds requirements that limited partnerships must meet to qualify as voting interest entities.	~~First quarter 2016~~	As a result of adopting this standard, we no longer consolidate ONEOK Partners under the presumption that a general partner should consolidate a limited partnership. We concluded, however, that ONEOK Partners is a VIE and ONEOK is the primary beneficiary, and we therefore consolidate ONEOK Partners under the variable interest model of consolidation. There was no financial statement impact due to the change in consolidation methodology. See Note K for additional information.



~~Standard~~	~~Description~~	~~Date of Adoption~~	~~Effect on the Financial Statements or Other Significant Matters~~
~~Standards that are not yet adopted~~
ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory”	The standard requires that inventory, excluding inventory measured using last-in, first-out (LIFO) or the retail inventory method, be measured at the lower of cost or net realizable value.	First quarter 2017	~~We do~~As a result of adopting this guidance, we updated our accounting policy for inventory valuation accordingly. The financial impact of adopting this guidance was not ~~expect the adoption of this standard to materially impact us.~~material.
ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships”	The standard clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met.	First quarter 2017	~~We do not expect the adoption~~The impact of adopting this standard ~~to materially impact us.~~was not material.
ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments”	The standard clarifies the requirements for assessing whether a contingent call (put) option that can accelerate the payment of principal on a debt instrument is clearly and closely related to its debt host.	First quarter 2017	~~We do not expect the adoption~~The impact of adopting this standard ~~to materially impact us.~~was not material.
ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting”	The standard provides simplified accounting for share-based payment transactions in relation to income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows.	First quarter 2017	~~We are evaluating~~As a result of adopting this guidance, we recorded an adjustment increasing beginning retained earnings and deferred tax assets in the ~~impact~~first quarter 2017 of approximately $73 million to recognize previously unrecognized cumulative excess tax benefits related to share-based payments on a modified retrospective basis. Prospectively, all share-based payment tax effects will be recorded in earnings. The other effects of adopting this standard were not material.



Standard	Description	Date of Adoption	Effect on ~~us.~~the Financial Statements or Other Significant Matters
Standards that are not yet adopted
ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)”	The standard outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendment also requires more extensive disaggregated revenue disclosures in interim and annual financial statements.	First quarter 2018	We are evaluating the impact of this standard on us. Our evaluation process includes a review of our and ONEOK Partners’ contracts and transaction types across all of the business segments. In addition, we are currently evaluating the methods of adoption and analyzing the impact of the standard on our internal controls, accounting policies and financial statements and disclosures. We expect to determine our method of adoption when we complete our evaluation of the impact of the standard and the implications of each adoption method.
ASU 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities”	The standard requires all equity investments, other than those accounted for using the equity method of accounting or those that result in consolidation of the investee, to be measured at fair value with changes in fair value recognized in net income, eliminates the available-for-sale classification for equity securities with readily determinable fair values and eliminates the cost method for equity investments without readily determinable fair values.	First quarter 2018	We are evaluating the impact of this standard on us.
ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments”	The standard clarifies the classification of certain cash receipts and cash payments on the statement of cash flows where diversity in practice has been identified.	First quarter 2018	We are evaluating the impact of this standard on us.
ASU 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”	The standard requires the service cost component of net benefit cost to be reported in the same line item or items as other compensation costs from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations.	First quarter 2018	We are evaluating the impact of this standard on us.
ASU 2016-02, “Leases (Topic 842)”	The standard requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. It also requires qualitative disclosures along with specific quantitative disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing and uncertainty of cash flows arising from leases.	First quarter 2019	We are evaluating our current leases and the impact of ~~this~~the standard on ~~us.~~our internal controls, accounting policies and financial statements and disclosures.
ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments”	The standard requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented net of the allowance for credit losses to reflect the net carrying value at the amount expected to be collected on the financial asset; and the initial allowance for credit losses for purchased financial assets, including available-for-sale debt securities, to be added to the purchase price rather than being reported as a credit loss expense.	First quarter 2020	We are evaluating the impact of this standard on us.
ASU 2017-04, “Intangibles- Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment”	The standard simplifies the subsequent measurement of goodwill by eliminating the requirement to calculate the implied fair value of goodwill under step 2. Instead, an entity will recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. The standard does not change step zero or step 1 assessments.	First quarter 2020	We are evaluating the impact of this standard on us.


B.	ACQUISITION OF ONEOK PARTNERS

On January 31, 2017, we and ONEOK Partners entered into the Merger Agreement pursuant to which we will acquire all of ONEOK Partners’ outstanding common units representing limited partner interests in ONEOK Partners not already directly or indirectly owned by us in an all stock-for-unit transaction at a ratio of 0.985 of a share of ONEOK common stock per common unit of ONEOK Partners, in a taxable transaction to ONEOK Partners’ common unitholders. Following completion of the Merger Transaction, all of ONEOK Partners’ outstanding common units will be directly or indirectly owned by us and will no longer be publicly traded. All of our and ONEOK Partners’ outstanding debt is expected to remain outstanding. We, ONEOK Partners and the Intermediate Partnership expect to issue, to the extent not already in place, guarantees of the indebtedness of ONEOK and ONEOK Partners.

A Special Committee of our Board of Directors, the Conflicts Committee of the Board of Directors of the general partner of ONEOK Partners and the Board of Directors of the general partner of ONEOK Partners each unanimously approved the Merger Agreement. Subject to customary approvals and conditions, the Merger Transaction is expected to close late in the second quarter or early in the third quarter of 2017. The Merger Transaction is subject to the approval of ONEOK Partners’ common unitholders and the approval by our shareholders of the issuance of ONEOK common shares in the Merger Transaction.

The Merger Agreement contains certain termination rights, including the right for either us or ONEOK Partners, as applicable, to terminate the Merger Agreement if the closing of the transactions contemplated by the Merger Agreement has not occurred on or before September 30, 2017. In the event of termination of the Merger Agreement under certain circumstances, we may be required to pay ONEOK Partners a termination fee in the form of a temporary reduction in incentive distributions (up to, in certain instances, $300 million) and, under other certain circumstances, ONEOK Partners may be required to pay us a termination fee (up to, in certain instances, $300 million in cash).

If the Merger Transaction closes, the expected changes in our ownership interest in ONEOK Partners will be accounted for as an equity transaction pursuant to ASC 810 as we expect to continue to control ONEOK Partners, and no gain or loss will be recognized in our consolidated statements of income resulting from the Merger Transaction. In addition, the tax effects of the Merger Transaction will be reported as adjustments to other assets, deferred income taxes and additional paid-in capital consistent with ASC 740, Income Taxes (ASC 740).


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

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

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

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

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

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

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

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

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

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


	September 30, 2016																		March 31, 2017
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)			Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)																		(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	9,051		$	—		$	2,858		$	11,909		$	(7,389	)	$	4,520		$	3,293		$	—		$	14,675		$	17,968		$	(17,217	)	$	751
Physical contracts	—			—			98			98			—			98			—			—			508			508			—			508
Interest-rate contracts																			—			47,914			—			47,914			—			47,914
Total derivative assets	$	9,051		$	—		$	2,956		$	12,007		$	(7,389	)	$	4,618		$	3,293		$	47,914		$	15,183		$	66,390		$	(17,217	)	$	49,173
Derivative liabilities
Commodity contracts
Financial contracts	$	(12,175	)	$	—		$	(9,846	)	$	(22,021	)	$	22,021		$	—		$	(15,757	)	$	—		$	(14,562	)	$	(30,319	)	$	29,973		$	(346	)
Physical contracts	—			—			(3,173		)	(3,173		)	—			(3,173		)	—			—			(1,393		)	(1,393		)	—			(1,393		)
Interest-rate contracts	—			(69,103		)	—			(69,103		)	—			(69,103		)	—			(11,316		)	—			(11,316		)	—			(11,316		)
Total derivative liabilities	$	(12,175	)	$	(69,103	)	$	(13,019	)	$	(94,297	)	$	22,021		$	(72,276	)	$	(15,757	)	$	(11,316	)	$	(15,955	)	$	(43,028	)	$	29,973		$	(13,055	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At ~~September 30, 2016,~~March 31, 2017, we held no cash and posted ~~$27.4~~$30.6 million of cash with various counterparties, including ~~$14.6~~$12.8 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining ~~$12.8~~$17.8 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets.

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


	December 31, 2015																		December 31, 2016
	Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)			Level 1			Level 2			Level 3			Total - Gross			Netting (a)			Total - Net (b)
	(Thousands of dollars)																		(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	38,921		$	—		$	7,253		$	46,174		$	(42,414	)	$	3,760		$	1,147		$	—		$	4,564		$	5,711		$	(4,760	)	$	951
Physical contracts	—			—			3,591			3,591			—			3,591
Interest-rate contracts																			—			47,457			—			47,457			—			47,457
Total derivative assets	$	38,921		$	—		$	10,844		$	49,765		$	(42,414	)	$	7,351		$	1,147		$	47,457		$	4,564		$	53,168		$	(4,760	)	$	48,408
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,513	)	$	—		$	(3,513	)	$	(8,026	)	$	8,026		$	—		$	(31,458	)	$	—		$	(24,861	)	$	(56,319	)	$	56,319		$	—
Physical contracts																			—			—			(3,022		)	(3,022		)	—			(3,022		)
Interest-rate contracts	—			(9,936		)	—			(9,936		)	—			(9,936		)	—			(12,795		)	—			(12,795		)	—			(12,795		)
Total derivative liabilities	$	(4,513	)	$	(9,936	)	$	(3,513	)	$	(17,962	)	$	8,026		$	(9,936	)	$	(31,458	)	$	(12,795	)	$	(27,883	)	$	(72,136	)	$	56,319		$	(15,817	)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, ~~2015,~~2016, we held ~~$34.4~~no cash and posted $67.7 million of cash ~~from~~with various counterparties, including $51.6 million of cash collateral that is offsetting derivative net ~~asset~~liability positions under master-netting arrangements in the table ~~above under master-netting arrangements and had no~~above. The remaining $16.1 million of cash collateral ~~posted.~~in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets.

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

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


	Three Months Ended						Nine Months Ended							Three Months Ended
	September 30,						September 30,							March 31,
Derivative Assets (Liabilities)	2016			2015			2016			2015				2017			2016
	(Thousands of dollars)												(Thousands of dollars)
Net assets (liabilities) at beginning of period	$	(14,021	)	$	10,387		$	7,331		$	9,285			$	(23,319	)	$	7,331
Total realized/unrealized gains (losses):
Included in earnings (a)	920			(15		)	492			95				913			(745		)
Included in other comprehensive income (loss)	3,038			(5,076		)	(17,886		)	(4,084		)		21,634			(6,552		)
Net assets (liabilities) at end of period	$	(10,063	)	$	5,296		$	(10,063	)	$	5,296			$	(772	)	$	34

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

Realized/unrealized gains (losses) include the realization of derivative contracts through maturity. During the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015,~~ gains or losses included in earnings attributable to the change in unrealized gains or losses relating to assets and liabilities still held at the end of each reporting period were not material.

We recognize transfers into and out of the levels in the fair value hierarchy as of the end of each reporting period. During the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015,~~ there were no transfers between levels.

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

The estimated fair value of our consolidated long-term debt, including current maturities, was ~~$9.3~~$8.9 billion and ~~$7.4~~$8.8 billion at ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015,~~2016, respectively. The book value of our consolidated long-term debt, including current maturities, was ~~$8.8 billion and $8.4~~$8.3 billion at ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015, respectively.~~2016. The estimated fair value of the aggregate of ONEOK’s and ONEOK Partners’ senior notes outstanding was determined using quoted market prices for similar issues with similar terms and maturities. The estimated fair value of our consolidated long-term debt is classified as Level 2.


C.D.	RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

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

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

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

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

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

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

We may also use other instruments including collars to mitigate commodity price risk. A collar is a combination of a purchased put option and a sold call option, which places a floor and a ceiling price for commodity sales being hedged.

The Natural Gas Gathering and Processing segment is exposed to commodity price risk as a result of ~~receiving commodities as~~retaining a portion of ~~its compensation for services~~the commodity sales proceeds associated with its POP with fee contracts. Under certain POP with fee contracts, ONEOK Partners’ fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. The Natural Gas Gathering and Processing segment also is exposed to basis risk between the various production and market locations where it receives and sells commodities. As part of our hedging strategy, we use the previously described commodity derivative financial instruments and physical-forward contracts to reduce the impact of price fluctuations related to natural gas, NGLs and condensate.

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

The Natural Gas Pipelines segment is exposed to commodity price risk because its intrastate and interstate natural gas pipelines retain natural gas from its customers for operations or as part of its fee for services provided. When the amount of natural gas consumed in operations by these pipelines differs from the amount provided by its customers, these pipelines must buy or sell natural gas, or store or use natural gas from inventory, which ~~can~~may expose them to commodity price risk depending on the regulatory treatment for this activity. To the extent that commodity price risk in the Natural Gas Pipelines segment is not mitigated by fuel cost-recovery mechanisms, we may use physical-forward sales or purchases to reduce the impact of price fluctuations related to natural gas. At ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015,~~2016, there were no financial derivative instruments with respect to ONEOK Partners’ natural gas pipeline operations.

Interest-rate risk - We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. As of ~~September 30,~~March 31, 2017 and December 31, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling ~~$1.0~~$1 billion to hedge the variability of ~~ONEOK Partners’~~its LIBOR-based interest ~~payments. In addition, in June 2016, ONEOK Partners entered into~~payments and forward-starting interest-rate swaps with notional amounts totaling ~~$750 million~~$1.2 billion to hedge the variability of interest payments on a portion of its forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is ~~issued, resulting in total notional amounts of this type of interest-rate swap of $1.2 billion at September 30, 2016, compared with $400 million at December 31, 2015.~~issued. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges.

Accounting Treatment - Our accounting treatment of derivative instruments is consistent with that disclosed in Note A of the Notes to consolidated Financial Statements in our Annual Report.

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


	September 30, 2016					December 31, 2015						March 31, 2017					December 31, 2016
	Assets (a)		(Liabilities) (a)			Assets (b)		(Liabilities) (b)			Location in our Consolidated Balance Sheets	Assets		(Liabilities)			Assets		(Liabilities)
	(Thousands of dollars)											(Thousands of dollars)
Derivatives designated as hedging instruments
Commodity contracts
Financial contracts	$	9,525	$	(20,376	)	$	39,255	$	(1,440	)	Other current assets/other current liabilities	$	6,154	$	(25,855	)	$	1,155	$	(49,938	)
											Other assets/deferred credits and other liabilities	6,683		—			210		(2,142		)
Physical contracts	98		(3,173		)	3,591		—			Other current assets/other current liabilities	87		(1,393		)	—		(3,022		)
											Other assets	421		—			—		—
Interest-rate contracts	—		(69,103		)	—		(9,936		)	Other current assets/other current liabilities	90		(11,316		)	—		(12,795		)
											Other assets	47,824		—			47,457		—
Total derivatives designated as hedging instruments	9,623		(92,652		)	42,846		(11,376		)		61,259		(38,564		)	48,822		(67,897		)
Derivatives not designated as hedging instruments
Commodity contracts
Financial contracts	2,384		(1,645		)	6,919		(6,586		)	Other current assets/other current liabilities	4,451		(3,796		)	4,346		(4,239		)
											Other assets/deferred credits and other liabilities	680		(668		)	—		—
Total derivatives not designated as hedging instruments	2,384		(1,645		)	6,919		(6,586		)		5,131		(4,464		)	4,346		(4,239		)
Total derivatives	$	12,007	$	(94,297	)	$	49,765	$	(17,962	)		$	66,390	$	(43,028	)	$	53,168	$	(72,136	)

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

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

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


		September 30, 2016					December 31, 2015						March 31, 2017					December 31, 2016
	Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver			Contract Type	Purchased/ Payor		Sold/ Receiver			Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:	Derivatives designated as hedging instruments:											Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures and swaps	—		(43.3		)	—		(27.1		)	Futures and swaps	—		(38.2		)	—		(38.4		)
- Natural gas (Bcf)	Put options	68.3		—			—		—			Put options	36.0		—			49.5		—
- Crude oil and NGLs (MMBbl)	Futures, forwards and swaps	—		(4.6		)	—		(2.3		)	Futures, forwards and swaps	0.3		(4.5		)	—		(3.6		)
Basis
- Natural gas (Bcf)	Futures and swaps	—		(43.3		)	—		(27.1		)	Futures and swaps	—		(38.2		)	—		(38.4		)
Interest-rate contracts (Millions of dollars)	Swaps	$	2,150.0	$	—		$	400.0	$	—		Swaps	$	2,150.0	$	—		$	2,150.0	$	—
Derivatives not designated as hedging instruments:	Derivatives not designated as hedging instruments:											Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)												Futures and swaps	3.5		—			0.4		—
- NGLs (MMBbl)	Futures, forwards and swaps	1.1		(0.9		)	0.6		(0.6		)	Futures, forwards and swaps	0.7		(2.6		)	0.5		(0.7		)
Basis
- Natural gas (Bcf)												Futures and swaps	3.5		—			0.4		—

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

Cash Flow Hedges - At ~~September 30, 2016,~~March 31, 2017, our Consolidated Balance Sheet reflected a net loss of ~~$154.4~~$139.1 million in accumulated other comprehensive loss. The portion of accumulated other comprehensive loss attributable to commodity derivative financial instruments is an unrealized loss of ~~$7.1~~$5.4 million, net of tax, which ~~will~~is expected to be realized within the next 2721 months as the forecasted transactions affect earnings. If commodity prices remain at current levels, we will realize approximately ~~$5.6~~$7.2 million in net losses, net of tax, over the next 12 months and approximately ~~$1.5~~$1.8 million in net ~~losses,~~gains, net of tax, thereafter. The amount deferred in accumulated other comprehensive loss attributable to settled interest-rate swaps is a loss of ~~$45.5~~$42.3 million, net of tax, which will be recognized over the life of the long-term, fixed-rate debt, including losses of ~~$6.4~~$6.5 million, net of tax, that will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive loss are attributable primarily to forward-starting interest-rate swaps with future settlement dates, which ~~will~~is expected to be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of the debt.

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


Derivatives in Cash Flow Hedging Relationships	Three Months Ended					Nine Months Ended							Three Months Ended
	September 30,					September 30,							March 31,
	2016		2015			2016			2015				2017		2016
	(Thousands of dollars)											(Thousands of dollars)
Commodity contracts	$	7,580	$	36,559		$	(39,396	)	$	47,650			$	27,328	$	11,678
Interest-rate contracts	958		(20,610		)	(59,217		)	(26,277		)		1,529		(31,611		)
Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion)	$	8,538	$	15,949		$	(98,613	)	$	21,373			$	28,857	$	(19,933	)

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

Derivatives in Cash Flow
Hedging Relationships
Location of Gain (Loss) Reclassified from
Accumulated Other Comprehensive
Loss into Net Income (Effective Portion)
Three Months Ended Nine Months Ended
September 30, September 30,
2016 2015 2016 2015

(Thousands of dollars)
Commodity contracts Commodity sales revenues $ 908
$ 22,770
$ 29,456
$ 54,020
Interest-rate contracts Interest expense (4,802 ) (4,554 ) (14,302 ) (12,869 )
Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion) $ (3,894 ) $ 18,216
$ 15,154
$ 41,151

Ineffectiveness related to our cash flow hedges for the three and nine months ended September 30, 2016 and 2015, was not material. In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings. For the three and nine months ended September 30, 2016 and 2015, there were no gains or losses due to the discontinuance of cash flow hedge treatment.



Derivatives in Cash Flow Hedging Relationships	Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income (Effective Portion)		Three Months Ended
			March 31,
			2017			2016
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues		$	(15,319	)	$	14,499
Interest-rate contracts	Interest expense		(5,329		)	(4,698		)
Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion)			$	(20,648	)	$	9,801

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

From time to time, ONEOK Partners may enter into financial derivative instruments that contain provisions that require it to maintain an investment-grade credit rating from S&P and/or Moody’s. If ONEOK Partners’ credit ratings on its senior unsecured long-term debt were to decline below investment grade, the counterparties to the derivative instruments could request collateralization on derivative instruments in net liability positions. There were no financial derivative instruments with contingent features related to credit risk at ~~September 30, 2016~~March 31, 2017.

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

At ~~September 30, 2016,~~March 31, 2017, the net credit exposure from our derivative assets is ~~primarily~~ with investment-grade companies in the financial services sector.


D.E.	~~SHORT-TERM BORROWINGS~~DEBT

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



	March 31, 2017			December 31, 2016
	(Thousands of dollars)
ONEOK
Senior unsecured obligations:
$700,000 at 4.25% due 2022	$	547,397		$	547,397
$500,000 at 7.5% due 2023	500,000			500,000
$100,000 at 6.5% due 2028	87,088			87,126
$100,000 at 6.875% due 2028	100,000			100,000
$400,000 at 6.0% due 2035	400,000			400,000
Total ONEOK senior notes payable	1,634,485			1,634,523
ONEOK Partners
Commercial paper outstanding, bearing a weighted-average interest rate of 1.51% and 1.27%, respectively	1,290,729			1,110,277
Senior unsecured obligations:
$400,000 at 2.0% due 2017	400,000			400,000
$425,000 at 3.2% due 2018	425,000			425,000
$1,000,000 term loan, variable rate, due 2019	1,000,000			1,000,000
$500,000 at 8.625% due 2019	500,000			500,000
$300,000 at 3.8% due 2020	300,000			300,000
$900,000 at 3.375 % due 2022	900,000			900,000
$425,000 at 5.0 % due 2023	425,000			425,000
$500,000 at 4.9 % due 2025	500,000			500,000
$600,000 at 6.65% due 2036	600,000			600,000
$600,000 at 6.85% due 2037	600,000			600,000
$650,000 at 6.125% due 2041	650,000			650,000
$400,000 at 6.2% due 2043	400,000			400,000
Guardian Pipeline
Weighted average 7.85% due 2022	42,345			44,257
Total debt	9,667,559			9,489,057
Unamortized portion of terminated swaps	19,756			20,186
Unamortized debt issuance costs and discounts	(66,110		)	(68,320		)
Current maturities of long-term debt	(410,650		)	(410,650		)
Short-term borrowings (a)	(1,290,729		)	(1,110,277		)
Long-term debt	$	7,919,826		$	7,919,996

(a) - Individual issuances of commercial paper under ONEOK Partners’ $2.4 billion commercial paper program generally mature in 90 days or less. However, these issuances are supported by and reduce the borrowing capacity under the ONEOK Partners Credit Agreement.

ONEOK Credit Agreement - In January 2016, we extended the term of the ONEOK Credit Agreement by one year to January 2020. The ONEOK Credit Agreement is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to ~~Consolidated~~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~~our ONEOK Credit Agreement, amounts outstanding under ~~the~~our ONEOK Credit Agreement, if any, may become due and payable immediately. At ~~September 30, 2016~~,March 31, 2017, ONEOK’s ratio of indebtedness to ~~Consolidated~~consolidated EBITDA was ~~2.1~~2.2 to 1, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement.

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

At ~~September 30,~~March 31, 2017 and December 31, 2016,~~, ONEOK~~ we had $1.1 million in letters of credit issued and no borrowings under the ONEOK Credit Agreement.

ONEOK Partners Credit Agreement- In January 2016, ONEOK Partners extended the term of the ONEOK Partners Credit Agreement by one year to January 2020. The ONEOK Partners Credit Agreement is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. At March 31, 2017, and December 31, 2016, ONEOK Partners had $14 million in letters of credit issued and no borrowings under the ONEOK Partners Credit Agreement. The ONEOK Partners Credit Agreement is available for general partnership ~~purposes.~~

~~ONEOK Partners~~purposes and had ~~$14 million~~available capacity of ~~letters of credit issued, no borrowings outstanding and~~ approximately ~~$1.7~~$1.1 billion ~~capacity available~~ at ~~September 30, 2016, under the ONEOK Partners Credit Agreement.~~March 31, 2017.

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~~ONEOK Partners’ credit rating. Under the terms of the ONEOK Partners Credit Agreement, based on ONEOK Partners’ current credit ratings, borrowings, if any, will accrue interest at LIBOR plus 117.5 basis points, and the annual facility fee is 20 basis points. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership. Borrowings under the ONEOK Partners Credit Agreement are currently nonrecourse to ONEOK.

The ONEOK Partners Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in the ONEOK Partners Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. If ONEOK Partners were to breach certain covenants in the ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement, if any, may become due and payable immediately. At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was ~~4.1~~4.2 to 1, and it was in compliance with all covenants under the ONEOK Partners Credit Agreement.

~~Neither~~2017 Credit Agreement - In April 2017, we entered into the 2017 Credit Agreement with a syndicate of banks, effective upon the closing of the Merger Transaction and the terminations of the 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,~~Credit Agreement and ONEOK Partners ~~does not guarantee~~Credit Agreement. The 2017 Credit Agreement is a $2.5 billion revolving credit facility and 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 our 2017 Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.75 to 1 at the ~~debt~~end of the quarter the Merger Transaction closes and the following two quarters; 5.5 to 1 for the subsequent two quarters; and 5.0 to 1 thereafter. If we consummate one or more acquisitions in which the aggregate purchase 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 is completed and the two following quarters.

The 2017 Credit Agreement includes a $100 million sublimit for the issuance of standby letters of credit and a $200 million sublimit for swingline loans. Under the terms of the 2017 Credit Agreement, we may request an increase in the size of the facility to an aggregate of $3.5 billion by either commitments from new lenders or increased commitments from existing lenders. The 2017 Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit ratings. Based on our expected credit ratings following the closing of the Merger Transaction, borrowings, if any, will accrue at LIBOR plus 110 basis points, and the annual facility fee is 15 basis points. The facility has the option to request two one-year extensions, subject to lender approval, and may be used for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit, and for other ~~similar commitments of ONEOK.~~general corporate purposes.

~~ONEOK Partners Commercial Paper Program~~Senior Unsecured Obligations -~~At September 30, 2016, ONEOK Partners had $694 million~~ All notes are senior unsecured obligations, ranking equally in right of ~~commercial paper outstanding under its $2.4 billion commercial paper program~~payment with ~~a weighted-average interest rate~~all of ~~1.15 percent. Amounts outstanding under ONEOK Partners’ commercial paper program reduce~~our existing and future unsecured senior indebtedness, and are structurally subordinate to any of the ~~borrowing capacity under the ONEOK Partners Credit Agreement.~~


E.	~~LONG-TERM DEBT~~

~~The following table sets forth our long-term~~existing and future debt ~~for the periods indicated:~~

September 30, December 31,
2016 2015

(Thousands of dollars)
ONEOK
$700,000 at 4.25% due 2022 $ 547,397
$ 547,397
$500,000 at 7.5% due 2023 500,000
500,000
$100,000 at 6.5% due 2028 87,137
87,516
$100,000 at 6.875% due 2028 100,000
100,000
$400,000 at 6.0% due 2035 400,000
400,000
Total ONEOK senior notes payable 1,634,534
1,634,913
ONEOK Partners

$650,000 at 3.25% due 2016 —
650,000
$450,000 at 6.15% due 2016 450,000
450,000
$400,000 at 2.0% due 2017 400,000
400,000
$425,000 at 3.2% due 2018 425,000
425,000
$1,000,000 term loan, variable rate, due 2019 1,000,000
—
$500,000 at 8.625% due 2019 500,000
500,000
$300,000 at 3.8% due 2020 300,000
300,000
$900,000 at 3.375% due 2022 900,000
900,000
$425,000 at 5.0% due 2023 425,000
425,000
$500,000 at 4.9% due 2025 500,000
500,000
$600,000 at 6.65% due 2036 600,000
600,000
$600,000 at 6.85% due 2037 600,000
600,000
$650,000 at 6.125% due 2041 650,000
650,000
$400,000 at 6.2% due 2043 400,000
400,000
Guardian Pipeline

Average 7.85% due 2022 46,170
51,907
Total ONEOK Partners long-term debt 7,196,170
6,851,907
Total long-term debt 8,830,704
8,486,820
Unamortized portion of terminated swaps 20,615
21,904
Unamortized debt issuance costs and discounts (70,525 ) (74,492 )
Current maturities (460,650 ) (110,650 )
Long-term debt, excluding current maturities $ 8,320,144
$ 8,323,582

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

ONEOK Partners ~~Debt Issuances~~issuances and ~~Maturities~~maturities - In January 2016, ONEOK Partners entered into the $1.0 billion senior unsecured ~~delayed-draw~~ Term Loan Agreement with a syndicate of banks. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus ~~a margin that is~~130 basis points based ~~on the credit ratings assigned to ONEOK Partners’ senior, unsecured, long-term indebtedness. Based~~ on ONEOK Partners’ current ~~applicable~~ credit ~~rating, borrowings on the Term Loan Agreement accrue at LIBOR plus 130 basis points.~~ratings. At ~~September 30, 2016,~~March 31, 2017, the interest rate was ~~1.83~~2.28 percent. The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term, subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding without penalty or premium and contains substantially the same covenants as the ONEOK Partners Credit Agreement. During the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under the agreement and used the proceeds to repay ~~its~~ $650 million ~~3.25 percent~~of senior notes at maturity, to repay amounts outstanding under ~~its~~ONEOK Partners’ commercial paper program and for general partnership purposes.

~~At September 30, 2016, ONEOK Partners’ $450 million, 6.15 percent senior notes due October 1, 2016, are reflected in current maturities of long-term debt in our Consolidated Balance Sheet.~~ In ~~October 2016,~~April 2017, ONEOK Partners ~~repaid its $450 million, 6.15 percent senior notes with~~entered into the first amendment to the Term Loan Agreement which, among other things, will add ONEOK as a ~~combination~~guarantor to the Term Loan Agreement effective upon the closing of ~~cash on hand and short-term borrowings.~~the Merger Transaction described in Note B.

~~In March 2015,~~Debt Guarantees - Neither we nor ONEOK Partners ~~completed an underwritten public offering~~guarantee the debt or other similar commitments of $800 million of senior notes, consisting of $300 million, 3.8 percent senior notes due 2020, and $500 million, 4.9 percent senior notes due 2025. The net proceeds, after deducting underwriting discounts, commissions and other expenses, were approximately $792.3 million.unaffiliated parties. ONEOK currently does not guarantee the debt, commercial paper, borrowings under the ONEOK Partners ~~used~~Credit Agreement or other similar commitments of ONEOK Partners, and ONEOK Partners currently does not guarantee the ~~proceeds~~debt or other similar commitments of ONEOK. Following the completion of the Merger Transaction described in Note B, we, ONEOK Partners and the Intermediate Partnership expect to ~~repay amounts outstanding under its commercial paper program~~issue, to the extent not already in place, guarantees of the indebtedness of ONEOK and ~~for general partnership purposes.~~ONEOK Partners.


F.	EQUITY

Dividends - Dividends paid on our common stock to shareholders of record at the close of business on ~~February 1, 2016, May 2, 2016, and August 8, 2016,~~January 30, 2017, were $0.615 per ~~share in each instance.~~share. A dividend of $0.615 per share was declared for shareholders of record at the close of business on ~~October 31, 2016,~~May 1, 2017, payable ~~November 14, 2016.~~May 15, 2017.

In April 2017, through a wholly owned subsidiary, we contributed 20,000 shares of newly issued Series E Non-Voting Perpetual Preferred Stock (Series E Preferred Stock), par value $0.01 per share, having an aggregate value of $20 million, to ONEOK Foundation, Inc. (the Foundation) for use in future charitable and nonprofit causes. The contribution will be recorded as a $20 million noncash expense in the second quarter of 2017. The Series E Preferred Stock is expected to pay quarterly dividends on each share of Series E Preferred Stock, when, as and if declared by our Board of Directors, at a rate of 5.5 percent per year.

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


G.	ACCUMULATED OTHER COMPREHENSIVE LOSS

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


	Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)			Accumulated Other Comprehensive Loss (a)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities (a)			Pension and Postretirement Benefit Plan Obligations (a) (b)			Unrealized Gains (Losses) on Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)			Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)												(Thousands of dollars)
January 1, 2016	$	(42,199	)	$	(84,543	)	$	(500	)	$	(127,242	)
January 1, 2017													$	(52,155	)	$	(101,236	)	$	(959	)	$	(154,350	)
Other comprehensive income (loss) before reclassifications	(25,597		)	9			(3,133		)	(28,721		)	7,491			3			73			7,567
Amounts reclassified from accumulated other comprehensive loss	(3,037		)	4,649			—			1,612			5,658			2,038			25			7,721
Net current period other comprehensive income (loss) attributable to ONEOK	(28,634		)	4,658			(3,133		)	(27,109		)	13,149			2,041			98			15,288
September 30, 2016	$	(70,833	)	$	(79,885	)	$	(3,633	)	$	(154,351	)
March 31, 2017													$	(39,006	)	$	(99,195	)	$	(861	)	$	(139,062	)

(a) All amounts are presented net of tax.

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

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


Details about Accumulated Other Comprehensive Loss Components	Three Months Ended						Nine Months Ended						Affected Line Item in the Consolidated Statements of Income	Three Months Ended						Affected Line Item in the Consolidated Statements of Income
	September 30,						September 30,							March 31,
	2016			2015			2016			2015				2017			2016
	(Thousands of dollars)													(Thousands of dollars)
Unrealized gains (losses) on risk-management assets/liabilities
Commodity contracts	$	908		$	22,770		$	29,456		$	54,020		Commodity sales revenues	$	(15,319	)	$	14,499		Commodity sales revenues
Interest-rate contracts	(4,802		)	(4,554		)	(14,302		)	(12,869		)	Interest expense	(5,329		)	(4,698		)	Interest expense
	(3,894		)	18,216			15,154			41,151			Income before income taxes	(20,648		)	9,801			Income before income taxes
	811			(2,957		)	(1,658		)	(5,621		)	Income tax expense	3,365			(1,276		)	Income tax expense
	(3,083		)	15,259			13,496			35,530			Net income	(17,283		)	8,525			Net income
Noncontrolling interests	(1,774		)	10,150			10,459			25,745			Less: Net income attributable to noncontrolling interests	(11,625		)	6,280			Less: Net income attributable to noncontrolling interests
	$	(1,309	)	$	5,109		$	3,037		$	9,785		Net income attributable to ONEOK	$	(5,658	)	$	2,245		Net income attributable to ONEOK


Pension and postretirement benefit plan obligations (a)
Amortization of net loss	$	(2,999	)	$	(4,422	)	$	(8,994	)	$	(13,268	)		$	(3,812	)	$	(2,998	)
Amortization of unrecognized prior service cost	416			392			1,246			1,176				415			415
	(2,583		)	(4,030		)	(7,748		)	(12,092		)	Income before income taxes	(3,397		)	(2,583		)	Income before income taxes
	1,033			1,612			3,099			4,837			Income tax expense	1,359			1,033			Income tax expense
	$	(1,550	)	$	(2,418	)	$	(4,649	)	$	(7,255	)	Net income attributable to ONEOK	$	(2,038	)	$	(1,550	)	Net income attributable to ONEOK

Unrealized gains (losses) on risk-management assets/liabilities of unconsolidated affiliates
														$	(96	)	$	—		Equity in net earnings from investments
														15			—			Income tax expense
														(81		)	—			Net income
Noncontrolling interests														(56		)	—			Less: Net income attributable to noncontrolling interests
														$	(25	)	$	—		Net income attributable to ONEOK

Total reclassifications for the period attributable to ONEOK	$	(2,859	)	$	2,691		$	(1,612	)	$	2,530		Net income attributable to ONEOK	$	(7,721	)	$	695		Net income attributable to ONEOK

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


H.	EARNINGS PER SHARE

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


	Three Months Ended September 30, 2016					Three Months Ended March 31, 2017
	Income		Shares	Per Share Amount		Income		Shares	Per Share Amount
	(Thousands, except per share amounts)					(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	92,720	211,309	$	0.44	$	87,361	211,619	$	0.41
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,561			—		1,983
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	92,720	212,870	$	0.44	$	87,361	213,602	$	0.41

Three Months Ended September 30, 2015
Income Shares
Per Share
Amount

(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common
stock
$ 86,017
210,296
$ 0.41
Diluted EPS from continuing operations

Effect of dilutive securities —
228

Income from continuing operations attributable to ONEOK available for common
stock and common stock equivalents
$ 86,017
210,524
$ 0.41

Nine Months Ended September 30, 2016
Income Shares
Per Share
Amount

(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock $ 263,289
211,038
$ 1.25
Diluted EPS from continuing operations

Effect of dilutive securities —
1,085

Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents $ 263,289
212,123
$ 1.24


	Nine Months Ended September 30, 2015					Three Months Ended March 31, 2016
	Income		Shares	Per Share Amount		Income		Shares	Per Share Amount
	(Thousands, except per share amounts)					(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	223,606	210,138	$	1.06	$	84,398	210,781	$	0.40
Diluted EPS from continuing operations
Effect of dilutive securities	—		371			—		290
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	223,606	210,509	$	1.06	$	84,398	211,071	$	0.40


I.	EMPLOYEE BENEFIT PLANS

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

Pension Benefits
Three Months Ended Nine Months Ended
September 30, September 30,
2016 2015 2016 2015

(Thousands of dollars)
Components of net periodic benefit cost
Service cost $ 1,622
$ 1,887
$ 4,866
$ 5,661
Interest cost 4,946
4,546
14,840
13,638
Expected return on assets (5,077 ) (5,213 ) (15,231 ) (15,639 )
Amortization of unrecognized prior service cost —
23
—
69
Amortization of net loss 2,737
3,987
8,210
11,961
Net periodic benefit cost $ 4,228
$ 5,230
$ 12,685
$ 15,690


	Postretirement Benefits												Pension Benefits						Postretirement Benefits
	Three Months Ended						Nine Months Ended						Three Months Ended						Three Months Ended
	September 30,						September 30,						March 31,						March 31,
	2016			2015			2016			2015			2017			2016			2017			2016
	(Thousands of dollars)												(Thousands of dollars)
Components of net periodic benefit cost
Service cost	$	149		$	186		$	447		$	558		$	1,722		$	1,622		$	165		$	149
Interest cost	601			587			1,803			1,760			4,655			4,947			565			601
Expected return on assets	(531		)	(564		)	(1,593		)	(1,692		)
Amortization of unrecognized prior service cost	(416		)	(415		)	(1,246		)	(1,245		)
Expected return on plan assets													(5,336		)	(5,077		)	(564		)	(531		)
Amortization of prior service cost (credit)													—			—			(415		)	(415		)
Amortization of net loss	262			435			784			1,307			3,392			2,737			420			261
Net periodic benefit cost	$	65		$	229		$	195		$	688		$	4,433		$	4,229		$	171		$	65


J.	UNCONSOLIDATED AFFILIATES

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


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
	2016		2015		2016		2015		2017		2016
	(Thousands of dollars)								(Thousands of dollars)
Northern Border Pipeline	$	17,854	$	16,156	$	52,251	$	51,131	$	18,817	$	18,674
Overland Pass Pipeline Company	13,886		10,538		40,798		27,048		13,566		13,304
Other	3,415		5,550		7,392		15,026		7,181		936
Equity in net earnings from investments	$	35,155	$	32,244	$	100,441	$	93,205	$	39,564	$	32,914

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					Three Months Ended
	September 30,				September 30,					March 31,
	2016		2015		2016		2015			2017		2016
	(Thousands of dollars)								(Thousands of dollars)
Income Statement
Operating revenues	$	143,967	$	135,474	$	423,170	$	390,793		$	154,280	$	136,572
Operating expenses	$	66,490	$	64,786	$	191,863	$	178,324		$	66,936	$	58,699
Net income	$	72,672	$	67,121	$	214,129	$	196,123		$	81,131	$	72,037

Distributions paid to ONEOK Partners	$	40,822	$	36,370	$	149,399	$	117,153		$	46,920	$	46,553

ONEOK Partners incurred expenses in transactions with unconsolidated affiliates of ~~$36.4~~$36.7 million and ~~$28.4~~$33.6 million for the three months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015, respectively, and $105.3 million and $74.2 million for the nine months ended September 30, 2016 and 2015,~~ respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline. Accounts payable to ONEOK Partners’ equity-method investees at ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015,~~2016, were ~~$11.5~~$13.1 million and ~~$8.0~~$11.1 million, respectively.

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

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

Roadrunner Gas Transmission - In March 2015, ONEOK Partners entered into a 50-50 joint venture with a subsidiary of Fermaca Infrastructure B.V. (Fermaca), a Mexico City-based natural gas infrastructure company, to construct a pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. During the nine months ended September 30, 2016, ONEOK Partners made contributions of approximately $55 million to Roadrunner, and expects to contribute approximately $10 million to Roadrunner during the remainder of 2016.

The Roadrunner limited liability company agreement provides that distributions to members are made on a pro rata basis according to each member’s ownership interest. ~~The Roadrunner Management Committee determines~~As the ~~amount~~operator, ONEOK Partners has been delegated the authority to determine such distributions in accordance with, and ~~timing of such distributions. Any changes to, or suspension of,~~on the ~~cash distributions from Roadrunner requires approval of~~frequency set forth in, the Roadrunner ~~Management Committee. Voting rights for the Roadrunner Management Committee are allocated on a pro rata basis according to each member’s ownership interest.~~limited liability company agreement. Cash distributions are equal to 100 percent of available cash, as defined in the limited liability company agreement.


K.	ONEOK PARTNERS

Ownership Interest in ONEOK Partners - Our ownership interest in ONEOK Partners is shown in the table below at ~~September 30, 2016~~March 31, 2017:



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

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

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

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

~~As we are the primary beneficiary of ONEOK Partners,~~beneficiary. Therefore, we consolidate ONEOK Partners in our consolidated financial statements; however, we are restricted from the assets and cash flows of ONEOK Partners except for the distributions we receive from ONEOK Partners. Distributions are declared quarterly by the board of ONEOK Partners’ general partner based on the terms of the Partnership Agreement. See Note NM for more information on ONEOK Partners’ results.

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


	September 30,		December 31,		March 31,		December 31,
	2016		2015		2017		2016
	(Thousands of dollars)				(Thousands of dollars)
Assets
Total current assets	$	1,128,794	$	883,164	$	1,065,745	$	1,174,245
Net property, plant and equipment	12,415,775		12,256,791		12,447,567		12,462,692
Total investments and other assets	1,774,989		1,787,631		1,828,623		1,832,410
Total assets	$	15,319,558	$	14,927,586	$	15,341,935	$	15,469,347
Liabilities
Total current liabilities	$	2,286,251	$	1,580,300	$	2,694,531	$	2,824,376
Long-term debt, excluding current maturities	6,691,663		6,695,312		6,290,952		6,291,307
Total deferred credits and other liabilities	188,254		154,631		193,797		175,844
Total liabilities	$	9,166,168	$	8,430,243	$	9,179,280	$	9,291,527

ONEOK receives distributions from ONEOK Partners through its general partner and limited partner interests, but otherwise the assets of ONEOK Partners cannot be used to settle obligations of ONEOK. ONEOK does not currently guarantee the debt, commercial paper or other similar commitments of ONEOK Partners, and the obligations of ONEOK Partners may only be settled using the assets of ONEOK Partners. ONEOK Partners does not currently guarantee the debt or other similar commitments of ONEOK. Following the completion of the Merger Transaction with ONEOK Partners described in Note B, we and ONEOK Partners and the Intermediate Partnership expect to issue, to the extent not already in place, guarantees of the indebtedness of ONEOK and ONEOK Partners.

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

ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units, up to an aggregate amount of $650 million. The program allows ONEOK Partners to offer and sell its common units at prices it deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

During the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017, and the year ended December 31, 2016, no common units were sold through ONEOK Partners’ “at-the-market” equity program.

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

We account for the difference between the carrying amount of our investment in ONEOK Partners and the underlying book value arising from issuance of common units by ONEOK Partners as an equity transaction. If ONEOK Partners issues common units at a price different than our carrying value per unit, we account for the premium or deficiency as an adjustment to paid-in capital.

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

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

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

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

In ~~October 2016,~~April 2017, a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) was declared for the ~~third~~first quarter ~~2016~~2017 and will be paid on ~~November 14, 2016,~~May 15, 2017, to unitholders of record at the close of business on ~~October 31, 2016.~~May 1, 2017.

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


	Three Months Ended				Nine Months Ended					Three Months Ended
	September 30,				September 30,					March 31,
	2016		2015		2016		2015			2017		2016
	(Thousands, except per unit amounts)								(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	2.37	$	2.37		$	0.79	$	0.79

General partner distributions	$	6,660	$	6,081	$	19,980	$	17,950		$	6,660	$	6,660
Incentive distributions	100,538		91,794		301,614		270,962			100,538		100,538
Distributions to general partner	107,198		97,875		321,594		288,912			107,198		107,198
Limited partner distributions to ONEOK	90,323		73,302		270,969		219,907			90,323		90,323
Limited partner distributions to noncontrolling interest	135,480		132,862		406,439		388,655			135,480		135,480
Total distributions paid	$	333,001	$	304,039	$	999,002	$	897,474		$	333,001	$	333,001

ONEOK Partners’ distributions are declared and paid within 45 days of the completion of each quarter. The following table ~~sets forth~~shows ONEOK Partners’ distributions declared for the periods ~~indicated and paid within 45 days of the end of the period:~~indicated:


	Three Months Ended				Nine Months Ended					Three Months Ended
	September 30,				September 30,					March 31,
	2016		2015		2016		2015			2017		2016
	(Thousands, except per unit amounts)								(Thousands, except per unit amounts)
Distribution per unit	$	0.79	$	0.79	$	2.37	$	2.37		$	0.79	$	0.79

General partner distributions	$	6,660	$	6,660	$	19,980	$	18,696		$	6,660	$	6,660
Incentive distributions	100,538		100,538		301,614		282,221			100,538		100,538
Distributions to general partner	107,198		107,198		321,594		300,917			107,198		107,198
Limited partner distributions to ONEOK	90,323		90,323		270,969		236,927			90,323		90,323
Limited partner distributions to noncontrolling interest	135,480		135,480		406,439		396,925			135,480		135,480
Total distributions declared	$	333,001	$	333,001	$	999,002	$	934,769		$	333,001	$	333,001

Affiliate Transactions - We provide ~~and are reimbursed for~~ a variety of services to our affiliates, including cash management and financial services, employee benefits, legal and administrative services by our employees and management, insurance and office space leased in our headquarters building and other field locations. Where costs are incurred specifically on behalf of an affiliate, the costs are billed directly to the affiliate by us. In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates. For the three months ended September 30, 2016 and 2015, $95.2 million and $89.3 million, respectively, of ONEOK Partners’ operating expenses were incurred with us. For the nine months ended September 30, 2016 and 2015, $285.1 million and $265.6 million, respectively, of ONEOK Partners’ operating expenses were incurred with us.

ONEOK Partners has an operating agreement with Roadrunner that provides for reimbursement or payment to it for management services and certain operating costs. Charges to Roadrunner included in operating income in our Consolidated

Statements of Income for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016, ~~were $2.5 million and $6.9 million, respectively. Charges to Roadrunner for the three and nine months ended September 30, 2015,~~ were not material.


L.	COMMITMENTS AND CONTINGENCIES

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

Legal Proceedings-Gas Index Pricing Litigation - ~~In October 2016, we reached~~On March 30, 2017, the United States District Court for the District of Nevada (the Court) entered an ~~agreement~~order granting summary judgment in ~~principle to settle the claims alleged against us and~~favor of our affiliate ONEOK Energy Services Company, L.P. ~~(“OESC”)~~(OESC), the lone defendant in ~~Reorganized FLI, Inc.~~the previously reported Sinclair case. The Court determined that the plaintiff’s claim is barred by a release obtained in ~~our Annual Report. The amount we expect~~a prior lawsuit against us and OESC. Upon entry of a final judgment, Sinclair Oil Corporation may pursue an appeal of this determination to ~~pay to settle this case is not material to our results~~the Ninth Circuit Court of ~~operations, financial position or cash flows and is expected to be paid with cash on hand.~~Appeals.

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

~~The above agreements in principle to settle do not apply to the~~ ~~Sinclair~~ ~~case, previously reported in our Annual Report.~~ We expect that future charges, if any, from the ultimate resolution of ~~this matter~~the Sinclair case will not be material to our results of operations, financial position or cash ~~flows.~~flows and are expected to be paid with cash on hand.

ONEOK Partners Class Action Litigation - On March 28, 2017, and April 7, 2017, two putative class action lawsuits captioned Juergen Krueger, Individually And On Behalf Of All Others Similarly Situated v. ONEOK Partners, L.P., et al (the First Complaint) and Max Federman, On Behalf of Himself and All Others Similarly Situated v. ONEOK Partners, L.P., et al (the Second Complaint, together with the First Complaint, the Complaints) were filed in the United States District Court for the Northern District of Oklahoma against ONEOK Partners and each of the members of the ONEOK Partners GP board of directors as defendants. The Complaints allege that the defendants violated Sections 14(a) and 20(a) of the Securities Exchange Act of 1934, as amended, and Rule 14a-9 promulgated thereunder, by causing a materially incomplete and misleading preliminary proxy statement to be filed with the SEC on March 7, 2017. Both Complaints seek various forms of relief, including injunctive relief and an award of attorneys’ fees and expenses. Each of the defendants believes the claims asserted in the Complaints are without merit and intends to vigorously defend against this lawsuit. At this time, however, it is not possible to predict the outcome of the proceedings or their impact on us, ONEOK Partners or the Merger Transaction.

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


M.	~~DISCONTINUED OPERATIONS~~

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

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

Nine Months Ended
September 30,
2016 2015

(Millions of dollars)
Beginning balance $ 36.3
$ 73.8
Settlements (16.2 ) (31.2 )
Accretion 0.4
0.8
Ending balance $ 20.5
$ 43.4

We expect future cash payments associated with released transportation and storage capacity contracts from the wind down of our former energy services business to total approximately $21 million, which consists of approximately $3 million to be paid in the remainder of 2016, $10 million in 2017, $4 million in 2018 and $4 million over the period 2019 through 2023.

~~Results of Operations of Discontinued Operations~~ - The results of operations for our former energy services business have been reported as discontinued operations for all periods presented. Income (loss) from discontinued operations, net of tax, in the Consolidated Statements of Income for the three and nine months ended September 30, 2016 and 2015, includes accretion expense, net of tax benefit, on the released contracts for our former energy services business.

~~Statement of Financial Position of Discontinued Operations~~ - At September 30, 2016, and December 31, 2015, assets and liabilities of discontinued operations in our Consolidated Balance Sheets relate primarily to deferred tax assets and capacity release obligations associated with our former energy services business.


N.	SEGMENTS

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

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

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

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

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

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

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

For the three months ~~and nine months~~ ended ~~September 30, 2016 and 2015, we~~March 31, 2017, ONEOK Partners had no single customer from which weit received 10 percent or more of our consolidated revenues.

For the three months ended March 31, 2016, ONEOK Partners had one customer, BP p.l.c. or its affiliates, from which it received approximately 12 percent of our consolidated revenues.

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


Three Months Ended September 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
Three Months Ended March 31, 2017																Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Total
	(Thousands of dollars)															(Thousands of dollars)
Sales to unaffiliated customers	$	361,717		$	1,905,273		$	90,401		$	516		$	2,357,907		$	400,149		$	2,244,000		$	104,924		$	2,749,073
Intersegment revenues	150,501			133,984			1,676			(286,161		)	—			261,127			147,984			1,894			411,005
Total revenues	512,218			2,039,257			92,077			(285,645		)	2,357,907			661,276			2,391,984			106,818			3,160,078
Cost of sales and fuel (exclusive of items shown separately below)	336,456			1,694,161			6,870			(285,894		)	1,751,593
Cost of sales and fuel (exclusive of depreciation and items shown separately below)																(488,384		)	(2,048,693		)	(16,603		)	(2,553,680		)
Operating costs	69,443			79,771			28,373			6,564			184,151			(71,789		)	(78,743		)	(31,753		)	(182,285		)
Equity in net earnings from investments																2,630			13,722			23,212			39,564
Other																234			(41		)	1,284			1,477
Segment adjusted EBITDA																$	103,967		$	278,229		$	82,958		$	465,154

Depreciation and amortization	44,994			40,751			12,057			748			98,550			$	(44,968	)	$	(41,115	)	$	(12,543	)	$	(98,626	)
(Gain) loss on sale of assets	(846		)	(5		)	(4,894		)	1			(5,744		)
Operating income	$	62,171		$	224,579		$	49,671		$	(7,064	)	$	329,357
Equity in net earnings from investments	$	2,596		$	13,960		$	18,599		$	—		$	35,155
Total assets																$	5,296,359		$	8,194,835		$	1,945,407		$	15,436,601
Capital expenditures	$	99,649		$	30,533		$	24,495		$	3,597		$	158,274		$	63,151		$	20,453		$	25,014		$	108,618

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of ~~$299.2~~$296.3 million, of which ~~$253.4~~$252.9 million related to sales within the segment and cost of sales and fuel of ~~$119.6 million and operating income of $118.5~~$116.5 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of ~~$61.0~~$68.9 million and cost of sales and fuel of ~~$7.8 million and operating income of $26.0~~$14.1 million.


Three Months Ended September 30, 2015	Natural Gas Gathering and Processing			Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations			Total
Three Months Ended March 31, 2017													Total Segments			Other and Eliminations			Total
	(Thousands of dollars)												(Thousands of dollars)
Reconciliations of total segments to consolidated
Sales to unaffiliated customers	$	294,948		$	1,522,224	$	81,246	$	528		$	1,898,946	$	2,749,073		$	538		$	2,749,611
Intersegment revenues	139,388			89,230		1,751		(230,369		)	—		411,005			(411,005		)	—
Total revenues	434,336			1,611,454		82,997		(229,841		)	1,898,946		$	3,160,078		$	(410,467	)	$	2,749,611
Cost of sales and fuel (exclusive of items shown separately below)	293,681			1,289,682		7,628		(230,182		)	1,360,809

Cost of sales and fuel (exclusive of depreciation and operating costs)													$	(2,553,680	)	$	409,837		$	(2,143,843	)
Operating costs	61,162			74,464		26,674		1,877			164,177		$	(182,285	)	$	(9,637	)	$	(191,922	)
Depreciation and amortization	37,286			39,317		10,914		782			88,299		$	(98,626	)	$	(793	)	$	(99,419	)
(Gain) loss on sale of assets	(132		)	498		77		283			726
Operating income	$	42,339		$	207,493	$	37,704	$	(2,601	)	$	284,935
Equity in net earnings from investments	$	4,350		$	10,912	$	16,982	$	—		$	32,244	$	39,564		$	—		$	39,564
Total assets													$	15,436,601		$	630,957		$	16,067,558
Capital expenditures	$	231,835		$	52,807	$	14,718	$	1,508		$	300,868	$	108,618		$	4,119		$	112,737



Three Months Ended March 31, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	317,046		$	1,371,425		$	85,474		$	1,773,945
Intersegment revenues	114,965			115,965			499			231,429
Total revenues	432,011			1,487,390			85,973			2,005,374
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(266,300		)	(1,156,950		)	(3,932		)	(1,427,182		)
Operating costs	(69,606		)	(73,182		)	(27,513		)	(170,301		)
Equity in net earnings from investments	2,815			13,347			16,752			32,914
Other	1,115			(436		)	3,059			3,738
Segment adjusted EBITDA	$	100,035		$	270,169		$	74,339		$	444,543

Depreciation and amortization	$	(41,851	)	$	(40,706	)	$	(11,179	)	$	(93,736	)
Total assets	$	5,196,190		$	8,016,245		$	1,847,352		$	15,059,787
Capital expenditures	$	141,497		$	34,207		$	17,948		$	193,652

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of ~~$252.8~~$281.8 million, of which ~~$204.7~~$230.8 million related to sales within the segment and cost of sales and fuel of ~~$112.7 million and operating income of $80.3~~$106.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of ~~$65.1~~$54.8 million and cost of sales and fuel of ~~$7.2 million and operating income of $24.7 million.~~

Nine Months Ended
September 30, 2016
Natural Gas
Gathering and
Processing

Natural Gas
Liquids (a)

Natural Gas
Pipelines (b)
Other and
Eliminations Total

(Thousands of dollars)
Sales to unaffiliated customers $ 971,834
$ 5,030,820
$ 262,276
$ 1,543
$ 6,266,473
Intersegment revenues 449,154
367,820
3,843
(820,817 ) —
Total revenues 1,420,988
5,398,640
266,119
(819,274 ) 6,266,473
Cost of sales and fuel (exclusive of items shown separately below) 902,747
4,376,345
15,914
(820,352 ) 4,474,654
Operating costs 208,353
236,722
85,075
22,855
553,005
Depreciation and amortization 133,258
122,153
34,634
2,230
292,275
(Gain) loss on sale of assets (2,331 ) (12 ) (7,133 ) (61 ) (9,537 )
Operating income $ 178,961
$ 663,432
$ 137,629
$ (23,946 ) $ 956,076
Equity in net earnings from investments $ 7,987
$ 41,211
$ 51,243
$ —
$ 100,441
Investments in unconsolidated affiliates $ 68,735
$ 470,635
$ 404,020
$ —
$ 943,390
Total assets $ 5,268,161
$ 8,257,203
$ 1,912,951
$ 543,720
$ 15,982,035
Noncontrolling interests in consolidated subsidiaries $ —
$ 158,352
$ —
$ 3,067,566
$ 3,225,918
Capital expenditures $ 325,820
$ 85,519
$ 71,721
$ 8,468
$ 491,528

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $878.5 million, of which $742.6 million related to sales within the segment, cost of sales and fuel of $339.1 million and operating income of $354.9 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $172.4 million, cost of sales and fuel of $19.1 million and operating income of $72.9$5.6 million.

Nine Months Ended
September 30, 2015
Natural Gas
Gathering and
Processing

Natural Gas
Liquids (a)

Natural Gas
Pipelines (b)
Other and
Eliminations Total

(Thousands of dollars)
Sales to unaffiliated customers $ 862,462
$ 4,726,617
$ 241,605
$ 1,620
$ 5,832,304
Intersegment revenues 487,559
229,804
5,053
(722,416 ) —
Total revenues 1,350,021
4,956,421
246,658
(720,796 ) 5,832,304
Cost of sales and fuel (exclusive of items shown separately below) 947,539
4,054,039
28,059
(721,871 ) 4,307,766
Operating costs 193,922
234,120
79,156
1,347
508,545
Depreciation and amortization 109,035
118,044
32,484
1,678
261,241
(Gain) loss on sale of assets (328 ) 579
76
283
610
Operating income $ 99,853
$ 549,639
$ 106,883
$ (2,233 ) $ 754,142
Equity in net earnings from investments $ 13,511
$ 27,585
$ 52,109
$ —
$ 93,205
Investments in unconsolidated affiliates $ 253,548
$ 484,403
$ 399,108
$ —
$ 1,137,059
Total assets $ 5,206,987
$ 8,041,064
$ 1,845,232
$ 415,015
$ 15,508,298
Noncontrolling interests in consolidated subsidiaries $ 4,066
$ 161,210
$ —
$ 3,457,557
$ 3,622,833
Capital expenditures $ 692,570
$ 185,360
$ 39,923
$ 12,463
$ 930,316

(a) - The Natural Gas Liquids segment has regulated and nonregulated operations. The Natural Gas Liquids segment’s regulated operations had revenues of $690.1 million, of which $556.4 million related to sales within the segment, cost of sales and fuel of $297.3 million and operating income of $218.8 million.

(b) - The Natural Gas Pipelines segment has regulated and nonregulated operations. The Natural Gas Pipelines segment’s regulated operations had revenues of $198.5 million, cost of sales and fuel of $22.6 million and operating income of $77.8 million.



Three Months Ended March 31, 2016	Total Segments			Other and Eliminations			Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
Sales to unaffiliated customers	$	1,773,945		$	514		$	1,774,459
Intersegment revenues	231,429			(231,429		)	—
Total revenues	$	2,005,374		$	(230,915	)	$	1,774,459

Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,427,182	)	$	231,444		$	(1,195,738	)
Operating costs	$	(170,301	)	$	(6,714	)	$	(177,015	)
Depreciation and amortization	$	(93,736	)	$	(742	)	$	(94,478	)
Equity in net earnings from investments	$	32,914		$	—		$	32,914
Total assets	$	15,059,787		$	441,362		$	15,501,149
Capital expenditures	$	193,652		$	2,759		$	196,411

Three Months Ended Nine Months Ended
September 30, September 30,
(Unaudited)
2016 2015 2016 2015

(Thousands of dollars)
Segment Adjusted EBITDA:
Natural Gas Gathering and Processing $ 109,837
$ 82,718
$ 320,170
$ 221,298
Natural Gas Liquids 279,256
255,745
826,036
692,991
Natural Gas Pipelines 80,304
65,166
223,185
201,112
Other (4,061 ) 2,228
(9,744 ) (3,473 )
Depreciation and amortization (98,550 ) (88,299 ) (292,275 ) (261,241 )
Interest expense, net of capitalized interest (118,240 ) (106,923 ) (355,463 ) (306,057 )
Income taxes (55,012 ) (38,298 ) (157,536 ) (123,948 )
AFUDC and other 1,258
(7,639 ) (3,584 ) (9,127 )
Income from continuing operations 194,792
164,698
550,789
411,555
Income (loss) from discontinued operations, net of tax (576 ) (3,860 ) (1,755 ) (4,144 )
Net income $ 194,216
$ 160,838
$ 549,034
$ 407,411



		Three Months Ended
		March 31,
		2017		2016
Reconciliation of income from continuing operations to total segment adjusted EBITDA	(Thousands of dollars)
Income from continuing operations		$	186,185	$	175,911
Add:
Interest expense, net of capitalized interest		116,462		118,247
Depreciation and amortization		99,419		94,478
Income taxes		54,941		50,066
Other noncash items and equity AFUDC		8,147		5,841
Total segment adjusted EBITDA		$	465,154	$	444,543


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

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

RECENT DEVELOPMENTS

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

Merger Transaction - On January 31, 2017, we and ONEOK Partners entered into the Merger Agreement pursuant to which we will acquire all of ONEOK Partners’ outstanding common units representing limited partner interests in ONEOK Partners not already directly or indirectly owned by us in an all stock-for-unit transaction at a ratio of 0.985 of a share of ONEOK common stock per common unit of ONEOK Partners, in a taxable transaction to ONEOK Partners’ unitholders. Following completion of the Merger Transaction, all of ONEOK Partners’ outstanding common units will be directly or indirectly owned by us and will no longer be publicly traded. All of our and ONEOK Partners’ outstanding debt is expected to remain outstanding. We, ONEOK Partners and the Intermediate Partnership expect to issue, to the extent not already in place, guarantees of the indebtedness of ONEOK and ONEOK Partners.

For additional information on this transaction, see Note B of the Notes to Consolidated Financial Statements in this Quarterly Report.

Ownership of ONEOK Partners - ONEOK and its subsidiaries own all of the general partner interest and a portion of the limited partner interests, which, together, represent a 41.2 percent ownership interest at ~~September 30, 2016,~~March 31, 2017, in ONEOK Partners (NYSE: OKS), one of the largest publicly traded master limited partnerships.

Business Update and Market Conditions - ONEOK Partners ~~has a~~operates predominantly fee-based ~~business~~businesses in each of ~~the~~its three reportable segments and we expect its consolidated earnings to be approximately 8590 percent fee-based in 2017. In the first quarter 2017, the Natural Gas Gathering and Processing segment’s fee revenues averaged 83 cents per MMBtu, compared with an average of 68 cents per MMBtu in the same period in 2016, due to ONEOK Partners’ contract restructuring efforts to address commodity price risk. ONEOK Partners connected three third-party natural gas processing plants in the Natural Gas Liquids segment and fee-based transportation services increased in the Natural Gas Pipelines segment, compared with the first quarter 2016. We continue to expect demand for midstream ~~nondiscretionary~~ services and infrastructure development to be primarily driven by producers who need to connect production with end-use markets where current infrastructure is ~~insufficient or nonexistent.~~insufficient. We also expect additional demand for ONEOK Partners’ services to support increased demand for NGL products from the petrochemical industry and NGL exporters, and increased demand for natural gas from power plants previously fueled by coal and natural gas ~~exports to Mexico.~~exports.

ONEOK Partners has available capacity on its integrated network of assets to grow fee-based earnings with minimal capital investments. ONEOK Partners is connected to supply in attractive, productive basins and has significant basin diversification across its asset footprint from the Williston, Permian and Powder River Basins to the STACK and SCOOP areas of the Anadarko Basin in Oklahoma. In addition, ONEOK Partners is connected to major market centers for natural gas and NGL products. While the Natural Gas Gathering and Processing and Natural Gas Liquids segments generate predominately fee-based earnings, those segments’ results of operations are exposed to volumetric risk. ONEOK Partners’ exposure to volumetric risk can result from reduced drilling activity, severe weather disruptions, operational outages and ethane rejection.

STACK and SCOOP -We expect each of ONEOK Partners’ business segments to benefit from increasing production activity in the Mid-Continent region from the highly productive STACK and SCOOP areas, where there was an increase in producer activity in late 2016 and early 2017, which we expect to continue throughout 2017. As producers continue to develop the STACK and SCOOP areas, we expect natural gas and NGL volumes on our systems to increase primarily in the second half of 2017, compared with 2016 volumes, and expect increased demand for ONEOK Partners’ services from producers that need incremental takeaway capacity for natural gas and NGLs out of the region. We anticipate NGL volume growth in the Mid-Continent region will also be driven by expected increases in ethane recovery in the second half of 2017 as new world-scale ethylene production projects, petrochemical plant modifications, plant expansions and export facilities near completion and begin coming on line.

In the Natural Gas Gathering and Processing segment, ONEOK Partners has more than 200,000 acres dedicated to it in the STACK and SCOOP areas. In the Natural Gas Liquids segment, ONEOK Partners is the largest NGL takeaway provider in the STACK and SCOOP areas through connections to more than 100 third-party natural gas processing plants in the Mid-Continent region. In the STACK and SCOOP areas, ONEOK Partners connected one third-party natural gas processing plant in the first quarter 2017 and expects to connect two additional third-party natural gas processing plants to its NGL system in the remainder of 2017. In the Natural Gas Pipelines segment, ONEOK Partners is connected to more than 30 natural gas processing plants in Oklahoma, which have a total processing capacity of approximately 1.8 Bcf/d, and is expanding the ONEOK Gas Transmission Pipeline, with additional compression, to serve a firm commitment for the westbound transportation of 100 MMcf/d of natural gas out of the STACK and SCOOP areas.

Williston Basin -We expect each of ONEOK Partners’ business segments to benefit from increasing production activity in the Williston Basin, where there was an increase in producer activity in late 2016 and early 2017, which we expect to continue throughout 2017. In the Natural Gas Gathering and Processing segment, ONEOK Partners’ completed growth projects, including its Bear Creek natural gas processing plant and infrastructure project that was completed in August 2016, have increased its gathering and processing capacity and allowed it to capture natural gas from new wells being drilled and natural gas from wells that previously flared natural gas production. ONEOK Partners has available natural gas processing capacity in this basin of approximately 175 MMcf/d. In the Natural Gas Liquids segment,ONEOK Partners is the largest NGL takeaway provider in the basin through connections to more than 10 natural gas processing plants, both third-party and its own, and ONEOK Partners connected one new third-party natural gas processing plant in the Rocky Mountain region in the first quarter 2017. Volumes being flared on ONEOK Partners’ dedicated acreage averaged approximately 60-80 MMcf/d in the first quarter 2017 and represent future volume growth opportunities in the Natural Gas Liquids and Natural Gas Gathering and Processing segments.

In this region, ONEOK Partners experienced severe winter weather during the first quarter of 2017 that temporarily reduced its natural gas volumes in the Natural Gas Gathering and Processing segment, which had an unfavorable impact on our financial results.

Permian Basin -We expect the Natural Gas Liquids ~~segment’s earnings~~and Natural Gas Pipelines business segments to ~~be approximately 90 percent fee-based~~benefit from increasing production activity in ~~2016.~~the Permian Basin from the highly productive Delaware and Midland Basins, where there was an increase in producer activity in late 2016 and early 2017, which we expect to continue throughout 2017.

In the Natural Gas Liquids segment, ONEOK Partners is well-positioned in the Permian Basin and is connected ~~seven~~to nearly 40 third-party natural gas processing plants ~~and~~through its ~~Lonesome Creek processing plant to its natural gas liquids system in 2015 and five~~West Texas LPG joint venture. In the Permian Basin, ONEOK Partners connected one third-party natural gas ~~processing plants and its Bear Creek~~ processing plant in the first ~~nine months~~quarter 2017 and expects to connect one additional third-party natural gas processing plant in the remainder of ~~2016, favorably impacting~~2017. In the Natural Gas ~~Liquids segment’s fee-based volume growth. In this~~Pipelines segment, we believe ONEOK Partners is well-positioned ~~to capture future increases in NGL transportation and fractionation volumes due to increased demand~~ in the ~~petrochemical industry~~Delaware Basin and has a significant position in the Midland Basin. ONEOK Partners is connected to more than 25 natural gas processing plants serving the Permian Basin, which have a total processing capacity of approximately 1.9 Bcf/d. The Roadrunner pipeline transports natural gas from the ~~expected completion of ethylene production projects~~Permian Basin in West Texas to the Mexican border near El Paso, Texas, and ~~NGL export activity without significant additional infrastructure needs or capital spending on~~is fully subscribed with 25-year firm demand charge, fee-based agreements. The Roadrunner pipeline connects with ONEOK Partners’ ~~system.~~existing natural gas pipeline and storage infrastructure in Texas and, together with its WesTex intrastate natural gas pipeline expansion project, creates a platform for future opportunities to deliver natural gas supply to Mexico. Roadrunner’s long-term firm demand transportation service contracts provide markets in Mexico access to upstream supply basins in West Texas and the Mid-Continent region, which adds location and price diversity to their supply mix and supports the plan of Mexico’s national electric utility, Comisión Federal de Electricidad, to replace oil-fueled power plants with natural gas-fueled power plants, which are more economical and produce fewer GHG emissions.

Ethane ~~rejection~~Opportunity -Ethane recovery levels by natural gas processors delivering to ONEOK Partners’ ~~natural gas liquids gathering~~NGL system have ~~continued to fluctuate and~~recently increased, primarily in the Mid-Continent region. Ethane rejection levels across ONEOK Partners’ system averaged more than 150 MBbl/d in the first three months of 2017, compared with an average of more than 175 MBbl/d ~~during the first nine months of 2016, primarily~~ in the ~~Mid-Continent region.~~same period in 2016. While the volume of ethane recovered increased ~~modestly~~ during the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015,~~2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations. We expect ethane ~~rejection~~recovery levels to continue to fluctuate for the remainder of ~~2016 and into~~ 2017 as ~~the market begins to balance~~ ethane supply and demand begin to balance and ~~with changes in~~as the price differentials between ethane and natural ~~gas.~~gas change. We expect ethane recovery levels to increase, first in regions closest to market centers, as ethylene producers and NGL exporters increase their capacity to consume and export additional ethane feedstock volumes. Ethane demand is expected to ramp up as new world-scale ethylene production projects, petrochemical plant modifications, plant expansions and export facilities near completion and begin coming on linevolumes in the second half of 2017. We expect ~~increases in~~the future ethane recoveries to have a favorable impact on our financial results, ~~beginning~~ primarily in the second half of 2017.

In 2015, the Natural Gas Gathering and Processing segment restructured many POP with fee contracts associated with a significant amount of its gathered volumes to increase the fee component in the contracts. These restructured contracts and increased natural gas gathered and processed volumes favorably impacted ONEOK Partners’ results in the first nine months of 2016, and we expect to continue to receive the benefit of the improved earnings from these contracts and volumes. In the first nine months of 2016, the Natural Gas Gathering and Processing segment’s fee revenues averaged 73 cents per MMBtu, compared with an average of 39 cents per MMBtu in the same period in 2015. As a result of these restructured contracts, we expect the Natural Gas Gathering and Processing segment’s earnings to be more than 75 percent fee-based in 2016. To mitigate the impact of its remaining commodity price exposure, ONEOK Partners has hedged a significant portion of the Natural Gas Gathering and Processing segment’s commodity price risk for 2016 and 2017 and has begun hedging commodity price risk for 2018.

With the emerging STACK and SCOOP areas in Oklahoma, we expect increasing producer activity in the Mid-Continent. ONEOK Partners has a strong presence in the area, with the Natural Gas Liquids segment’s gathering system connected to more than 100 third-party natural gas processing plants, the Natural Gas Gathering and Processing segment’s substantial acreage dedications in some of the most productive areas and the Natural Gas Pipelines segment’s broad footprint. We expect well completions in these areas to begin to ramp up in late 2016 and early 2017. As producers continue to develop the STACK

and SCOOP areas, we expect natural gas and NGL volumes to increase in 2017, compared with expected 2016 volumes, and increased demand for ONEOK Partners’ services from producers that need incremental takeaway capacity for natural gas and NGLs out of the region.

Many of ONEOK Partners’ producer customers continue to drill and complete new wells in the most productive areas of the Williston Basin. A significant portion of ONEOK Partners’ Williston Basin gathering and processing assets are located in these areas, which typically produce at higher initial production rates compared with other areas and have higher natural gas to oil ratios. ONEOK Partners’ natural gas volumes gathered and processed and NGL volumes gathered and fractionated increased in the first nine months of 2016, compared with the same period in 2015, due primarily to the completion of six compressor stations during 2015, the addition of the 200 MMcf/d Lonesome Creek plant in the fourth quarter 2015 and ONEOK Partners’ 80 MMcf/d Bear Creek plant in the third quarter 2016, which allowed ONEOK Partners to capture a significant portion of natural gas volumes previously being flared by producers in the Williston Basin. Additionally, we expect to benefit from production from new wells drilled on ONEOK Partners’ dedicated acreage in the Williston Basin and wells that have been drilled previously but have not yet been completed. In 2017, we expect volume growth in the Williston Basin from the projects and production activities discussed above to be offset by natural production declines, which may cause ONEOK Partners’ natural gas and NGL volumes from this basin to be relatively unchanged in 2017, compared with expected 2016 volumes in the Natural Gas Gathering and Processing and Natural Gas Liquids segments.

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

We expect the current lower commodity price environment to continue throughout 2016 and into 2017, impacting ONEOK Partners’ net realized prices for natural gas, NGLs and condensate, and our financial results. If the low commodity price environment persists for a prolonged period or prices decline further, volumes across ONEOK Partners’ assets may grow more slowly than in the past or decline.

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

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

In addition to its growth projects, ONEOK Partners has available capacity on its integrated system to grow fee-based earnings with minimal capital investment, particularly in the Natural Gas Liquids segment. The Natural Gas Gathering and Processing and Natural Gas Liquids segments are well-positioned to capture future increases in volumes from the highly productive STACK and SCOOP areas in Oklahoma, where we expect an increase in producer activity in the remainder of 2016 and into 2017. The Natural Gas Liquids segment is connected to more than 100 third-party natural gas processing plants in the Mid-Continent and is one of the primary NGL takeaway providers for these emerging areas. Additionally, in the Natural Gas Liquids segment, we expect approximately 175 MBbl/d to 200 MBbl/d of future ethane recoveries that can be brought onto ONEOK Partners’ system with no additional capital expenditures required. In the Natural Gas Gathering and Processing

~~segment, ONEOK Partners has approximately 200 MMcf/d and 150 MMcf/d of available processing capacity in the Williston Basin and Mid-Continent region, respectively.~~

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

Dividends/Distributions - We declared a quarterly dividend of $0.615 per share ($2.46 per share on an annualized basis) in ~~October 2016.~~April 2017. ONEOK Partners declared a cash distribution of $0.79 per unit ($3.16 per unit on an annualized basis) in ~~October 2016~~April

2017 for the ~~third~~first quarter ~~2016.~~2017. The quarterly dividend and distribution will be paid ~~November 14, 2016,~~May 15, 2017, to shareholders and unitholders of record at the close of business on ~~October 31, 2016.~~

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

~~Goodwill Impairment Test~~ ~~- As the commodity price environment has remained relatively unchanged since 2015, we elected to perform a quantitative assessment, or Step~~May 1, analysis, to test our goodwill for impairment. The assessment included ONEOK Partners’ current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates. Our goodwill impairment analysis performed as of July 1, 2016, did not result in an impairment charge nor did our analysis reflect any reporting units at risk. In each reporting unit, the fair value substantially exceeded the carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of our reporting units is less than the carrying value of its net assets.2017.

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, 2016 vs. 2015 2016 vs. 2015
Financial Results 2016
2015
2016
2015 Increase (Decrease) Increase (Decrease)

(Millions of dollars)
Revenues
Commodity sales $ 1,840.5
$ 1,484.3
$ 4,757.3
$ 4,642.3
$ 356.2
24 % $ 115.0
2 %
Services 517.4
414.6
1,509.2
1,190.0
102.8
25 % 319.2
27 %
Total revenues 2,357.9
1,898.9
6,266.5
5,832.3
459.0
24 % 434.2
7 %
Cost of sales and fuel (exclusive of items shown separately below) 1,751.6
1,360.8
4,474.7
4,307.8
390.8
29 % 166.9
4 %
Operating costs 184.1
164.2
553.0
508.6
19.9
12 % 44.4
9 %
Depreciation and amortization 98.5
88.3
292.2
261.2
10.2
12 % 31.0
12 %
(Gain) loss on sale of assets (5.7 ) 0.7
(9.5 ) 0.6
6.4
*
10.1
*
Operating income $ 329.4
$ 284.9
$ 956.1
$ 754.1
$ 44.5
16 % $ 202.0
27 %
Equity in net earnings from investments $ 35.2
$ 32.2
$ 100.4
$ 93.2
$ 3.0
9 % $ 7.2
8 %
Interest expense, net of capitalized interest $ (118.2 ) $ (106.9 ) $ (355.5 ) $ (306.1 ) $ 11.3
11 % $ 49.4
16 %
Adjusted EBITDA $ 465.3
$ 405.9
$ 1,359.6
$ 1,111.9
$ 59.4
15 % $ 247.7
22 %
Capital expenditures $ 158.3
$ 300.9
$ 491.5
$ 930.3
$ (142.6 ) (47 %) $ (438.8 ) (47 %)

* Percentage change is greater than 100 percent.



		Three Months Ended						Three Months
		March 31,						2017 vs. 2016
Financial Results		2017			2016			Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales		$	2,216.7		$	1,283.5		$	933.2		73	%
Services		532.9			491.0			41.9			9	%
Total revenues		2,749.6			1,774.5			975.1			55	%
Cost of sales and fuel (exclusive of items shown separately below)		2,143.8			1,195.7			948.1			79	%
Operating costs		192.0			177.1			14.9			8	%
Depreciation and amortization		99.4			94.5			4.9			5	%
(Gain) loss on sale of assets		—			(4.2		)	(4.2		)	(100	%)
Operating income		$	314.4		$	311.4		$	3.0		1	%
Equity in net earnings from investments		$	39.6		$	32.9		$	6.7		20	%
Interest expense, net of capitalized interest		$	(116.5	)	$	(118.2	)	$	(1.7	)	(1	%)
Net income		$	186.2		$	175.0		$	11.2		6	%
Adjusted EBITDA		$	459.6		$	441.6		$	18.0		4	%
Capital expenditures		$	112.7		$	196.4		$	(83.7	)	(43	%)

See ~~Reconciliation~~reconciliation of ~~Adjusted~~net income to adjusted EBITDA ~~to Net Income~~ in the “Adjusted EBITDA” section.

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

Operating income and adjusted EBITDA increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, due primarily to higher natural gas and NGL volumes from ONEOK Partners’ completed capital-growth projects in the Natural Gas Gathering and Processing and Natural Gas Liquids segments, new plant connections and increased ethane recovery in the Natural Gas Liquids segment, and higher fees resulting from contract restructuring in the Natural Gas Gathering and Processing ~~segment.~~segment, higher transportation services due to increased firm demand charge contracted capacity in the Natural Gas Pipelines segment and increased optimization and marketing activities in the Natural Gas Liquids segment resulting primarily from wider location price differentials. These increases were offset partially by lower ~~net realized NGL and natural gas prices~~volumes due to severe winter weather in the Natural Gas Gathering and Processing segment, higher operating costs related to increased ad valorem taxes in the Natural Gas Liquids and Natural Gas Pipelines segments and higher labor and employee-related costs. Operating income was also impacted by higher depreciation expense in the three months ended March 31, 2017, compared with the same period in 2016, due to projects completed in ~~2015, higher~~2016. In the three months ended March 31, 2017, we incurred operating costs ~~associated with~~related to the ~~growth~~Merger Transaction of ONEOK Partners’ operations in the Natural Gas Gathering and Processing segment, higher employee-related costs associated with incentive and medical benefit plans in all three of the segments and higher costs associated with the impact of the noncash mark to market of a share-based deferred compensation plan.approximately $7 million.

Equity in net earnings from investments increased for the three ~~and nine~~ months ended September 30, 2016, compared with the same periods in 2015, due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline, offset partially by lower equity earnings from ONEOK Partners’ Powder River Basin equity investments.

~~Interest expense increased for the three months ended September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015, primarily as a result of higher interest costs incurred associated with ONEOK Partners’ borrowing under the Term Loan Agreement during the first quarter~~ 2016, higher short-term borrowing rates and lower capitalized interest due to lower spending on capital-growth projects and higher interest costs incurred associated with our $500 million debt issuance in August 2015. Interest expense increased for the nine months ended September 30, 2016, compared with the same period in 2015, primarily as a result of the items discussed above and higher interest costs incurred associated with ONEOK Partners’ issuance of $800 million of senior notes in March 2015.

~~Adjusted EBITDA increased for the three and nine months ended September 30, 2016, compared with the same periods in 2015,~~ due primarily to higher ~~natural gas gathered and NGL volumes from ONEOK Partners’ completed capital-growth projects~~firm transportation revenues on Roadrunner, which added capacity in the Natural Gas Gathering and Processing and Natural Gas Liquids segments, new plant connections and increased ethane recovery in the Natural Gas Liquids segment, and higher fees resulting from contract restructuring in the Natural Gas Gathering and Processing segment. These increases were offset partially by lower net realized NGL and natural gas prices in the Natural Gas Gathering and Processing segment, higher costs associated with the growth of ONEOK Partners’ operations in the Natural Gas Gathering and Processing segment and higher employee-related costs associated with incentive and medical benefit plans in all three of the segments.October 2016 that is fully subscribed under long-term firm demand charge contracts.

Capital expenditures decreased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, due to projects placed in service in ~~2015, spending reductions to align with customer needs~~2016 and ~~lower~~fewer well ~~connect activities~~connections in the Natural Gas Gathering and Processing segment due to ~~a reduction~~the impact of severe winter weather in ~~drilling and completion activity.~~the Williston Basin in the first quarter 2017.

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

This segment gathers and processes natural gas in the Williston Basin, which is located in portions of North Dakota and Montana, including the oil-producing, NGL-rich Bakken Shale and Three Forks ~~formation,~~formations, and is an active drilling region. ONEOK Partners’ completed growth projects, including its ~~most active region with continued volume growth~~Bear Creek natural gas processing plant and ~~additional~~infrastructure project that was completed in August 2016, have increased its gathering and processing ~~infrastructure needs.~~capacity and allowed it to capture natural gas from new wells being drilled and from wells that previously flared natural gas production. The Mid-Continent region ~~consists of Western Oklahoma, which~~is an active drilling region and includes the NGL-rich STACK and SCOOP areas in the Anadarko Basin and the Cana-Woodford Shale, Woodford Shale, Springer Shale, Meramec, Granite Wash and Mississippian Lime formation of Oklahoma and Kansas; and the ~~Mississippian Lime;~~Hugoton and ~~Southwest Kansas, which includes the Hugoton Basin,~~ Central Kansas Uplift ~~Basin and the Mississippian Lime.~~Basins of Kansas. The Powder River Basin is primarily located in Wyoming, which includes the NGL-rich Niobrara

Shale and Frontier, Turner and Sussex formations where ONEOK ~~Partners’ Sage Creek system~~Partners provides gathering and processing services to customers in the southeast portion of Wyoming.

Revenues for this segment are derived primarily from POP ~~contracts~~ with fee ~~components~~contracts and fee-only contracts. Under a POP ~~contract~~ with fee ~~components,~~contract, ONEOK Partners charges fees for gathering, treating, compressing and processing the producer’s natural gas. ONEOK Partners also generally purchases the producer’s raw natural gas, ~~and retains a percentage of the proceeds from the sale of~~which it processes into residue natural gas and NGLs, then it sells these commodities and associated condensate ~~and/or NGLs.~~to downstream customers. ONEOK Partners remits sales proceeds to the producer according to the contractual terms and retains its portion. Over time as these contracts are renewed or restructured, ONEOK Partners has generally increased the fee ~~components and reduced the percent of proceeds retained from the sale of the commodities.~~components. Additionally, under certain POP with fee contracts the fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. With a fee-only contract, ONEOK Partners is paid a fee for the services it provides, based on volumes gathered, processed, treated and/or compressed.

ONEOK Partners has restructured many of its contracts to significantly increase its fees, and as a result of these restructured contracts, ~~we expect~~ the Natural Gas Gathering and Processing segment’s earnings ~~to be more than 75 percent fee-based in 2016.~~are primarily fee-based. These restructured contracts favorably impacted ONEOK Partners’ results for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, and we expect to continue to receive the benefit of improved earnings from these contracts. ONEOK Partners’ ~~NGLs, natural gas and crude oil~~direct commodity price sensitivity in this segment has ~~continued to decrease in 2016~~decreased as a result of these restructured contracts. ~~Additionally,~~To mitigate the impact of its remaining commodity price exposure, ONEOK Partners ~~uses commodity derivative instruments~~has hedged a significant portion of its Natural Gas Gathering and physical-forward contracts to reduce its near-term sensitivity to fluctuations in the natural gas, crude oil and NGL commodity prices under POP with fee contracts. ONEOK Partners will continue to seek opportunities to increase its fee-based earnings and reduce itsProcessing segment’s commodity price ~~exposure.~~risk for 2017 and 2018. This segment has substantial acreage dedications in some of the most productive areas of the Williston Basin and Mid-Continent region, specifically the STACK and SCOOP, which helps to mitigate volumetric risk.

ONEOK Partners’ natural gas gathered and processed volumes in the Williston Basin ~~increased~~decreased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015, despite~~2016, due primarily to severe winter weather in the ~~reductions in producer drilling activity,~~first quarter 2017. We expect that Williston Basin volumes for 2017 will increase slightly compared with 2016 due to the following:

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

producers focusing their drilling and completion in the most productive areas in which ONEOK Partners has substantial acreage dedications and significant gathering and processing ~~assets, which typically produce at higher initial production rates compared with other areas and have higher natural gas to oil ratios; and~~assets;

continued improvements in production by producers due to enhanced completion techniques and more efficient drilling ~~rigs.~~rigs; and

the opportunity to capture additional natural gas from wells that currently flare natural gas production; offset partially by

natural production declines.

In the Mid-Continent region, ONEOK Partners has significant natural gas gathering and processing assets in Oklahoma and Kansas. With the emerging STACK and SCOOP areas, we anticipate increased producer activity, where ONEOK Partners has substantial acreage dedications in these productive areas. Although volumes decreased for the three months ended March 31, 2017, compared with the same period in 2016, we expect ONEOK Partners’ ~~producer customers continue~~average natural gas volumes to ~~focus their~~grow in 2017 due to continued drilling and completion ~~activities in~~activity, offset partially by the ~~core STACK, SCOOP and Cana-Woodford areas of Oklahoma, and recent~~natural production declines from existing wells ~~have shown strong results; however, several large multi-well pads previously scheduled~~connected to ~~be completed in late 2015 and early 2016 have been delayed until fourth quarter 2016 or early 2017.~~its system.

Growth Projects - ~~The Natural Gas Gathering and Processing~~In this segment, ~~invested~~ONEOK Partners is investing in growth projects in NGL-rich areas, including the Bakken Shale and Three Forks formation in the Williston Basin and STACK and SCOOP areas ~~Cana-Woodford Shale, Woodford Shale and Springer Shale~~of the Anadarko Basin, that ~~ONEOK Partners expects~~we expect will enable itONEOK Partners to meet the needs of crude oil and natural gas producers in those areas. Nearly all of the new natural gas production ~~in these areas~~ is from horizontally drilled wells in nonconventional resource areas. These wells tend to produce volumes at higher initial production rates resulting generally in higher initial decline rates than conventional vertical wells; however, the decline rates flatten out over time. These wells are expected to have long productive lives.

In ~~2015 and~~August 2016, ONEOK Partners completed the ~~following projects:~~



~~Completed Projects~~	~~Location~~	~~Capacity~~	~~Approximate~~ ~~Costs (a)~~	~~Completion Date~~
			(~~In millions~~)
~~Rocky Mountain Region~~
~~Lonesome Creek processing plant and infrastructure~~	~~Williston Basin~~	~~200 MMcf/d~~	~~$600~~	~~November 2015~~
~~Sage Creek infrastructure~~	~~Powder River Basin~~	~~Various~~	~~$35~~	~~December 2015~~
~~Natural gas compression~~	~~Williston Basin~~	~~100 MMcf/d~~	~~$75~~	~~December 2015~~
80 MMcf/d Bear Creek ~~processing plant and infrastructure~~	~~Williston Basin~~	~~80 MMcf/d~~	~~$230-$250~~	~~August 2016~~
~~Stateline de-ethanizers~~	~~Williston Basin~~	~~26 MBbl/d~~	~~$85~~	~~September 2016~~

~~(a) - Excludes AFUDC.~~

~~ONEOK Partners has the following natural gas~~ processing ~~plants~~plant and ~~related~~ infrastructure ~~suspended:~~



~~Projects in Progress~~	~~Location~~	~~Capacity~~	~~Approximate~~ ~~Costs (a)~~	~~Expected~~ ~~Completion Date~~
			(~~In millions~~)
~~Rocky Mountain Region~~
~~Bronco processing plant and infrastructure~~	~~Powder River Basin~~	~~50 MMcf/d~~	~~$130-$200~~	~~Suspended~~
~~Demicks Lake processing plant and infrastructure~~	~~Williston Basin~~	~~200 MMcf/d~~	~~$475-$670~~	~~Suspended~~
~~Mid-Continent Region~~
~~Knox processing plant and infrastructure~~	~~SCOOP~~	~~200 MMcf/d~~	~~$240-$470~~	~~Suspended~~
~~Total~~			~~$845-$1,340~~

~~(a) - Excludes AFUDC.~~

As a result of reductions in crude oil and natural gas drilling by producers due to the decline in crude oil, natural gas and NGL prices and the expectation of slower supply growth or declines, in 2015 ONEOK Partners suspended capital expenditures for certain natural gas processing plants and field infrastructure. ONEOK Partners could resume its suspended capital-growth projects when market conditions improve and its customers’ needs change. If the current commodity price environment persists for a prolonged period, it may further impact the timing or demand for these projects and additional infrastructure projects or growth opportunitiesproject in the ~~future.~~Williston Basin for approximately $240 million, excluding capitalized interest.

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

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

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


	Three Months Ended						Nine Months Ended						Three Months					Nine Months						Three Months Ended						Three Months
	September 30,						September 30,						2016 vs. 2015					2016 vs. 2015						March 31,						2017 vs. 2016
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)						2017			2016			Increase (Decrease)
	(Millions of dollars)																						(Millions of dollars)
NGL sales	$	134.9		$	118.7		$	381.9		$	423.1		$	16.2		14	%	$	(41.2	)	(10	%)		$	245.5		$	94.6		$	150.9		*
Condensate sales	13.8			12.3			41.4			39.9			1.5			12	%	1.5			4	%		19.0			12.7			6.3			50	%
Residue natural gas sales	186.8			211.2			481.1			635.6			(24.4		)	(12	%)	(154.5		)	(24	%)		210.5			157.7			52.8			33	%
Gathering, compression, dehydration and processing fees and other revenue	176.7			92.1			516.6			251.4			84.6			92	%	265.2			*			186.3			167.0			19.3			12	%
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(336.5		)	(293.6		)	(902.7		)	(947.5		)	42.9			15	%	(44.8		)	(5	%)		(488.4		)	(266.3		)	222.1			83	%
Operating costs	(69.4		)	(61.2		)	(208.4		)	(193.9		)	8.2			13	%	14.5			7	%		(71.8		)	(69.6		)	2.2			3	%
Equity in net earnings from investments	2.6			4.4			8.0			13.5			(1.8		)	(41	%)	(5.5		)	(41	%)		2.6			2.8			(0.2		)	(7	%)
Other	0.9			(1.2		)	2.3			(0.8		)	2.1			*		3.1			*			0.3			1.1			(0.8		)	(73	%)
Adjusted EBITDA	$	109.8		$	82.7		$	320.2		$	221.3		$	27.1		33	%	$	98.9		45	%		$	104.0		$	100.0		$	4.0		4	%
Capital expenditures	$	99.6		$	231.8		$	325.8		$	692.6		$	(132.2	)	(57	%)	$	(366.8	)	(53	%)		$	63.2		$	141.5		$	(78.3	)	(55	%)

* Percentage change is greater than 100 percent.

See ~~Reconciliation~~reconciliation of ~~Adjusted~~net income to adjusted EBITDA ~~to Net Income~~ in the “Adjusted EBITDA” section.

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

Adjusted EBITDA increased ~~$27.1~~$4.0 million for the three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015,~~2016, primarily as a result of the following:

an increase of ~~$28.8 million due primarily to natural gas volume growth in the Williston Basin, offset partially by volume declines in the Mid-Continent region; and~~

~~an increase of $27.9~~$19.8 million due primarily to restructured contracts resulting in higher fee revenues from increased average fee rates, offset partially by a lower percentage of proceeds retained from the sale of commodities purchased under ONEOK Partners’ POP with fee contracts; offset partially by

a decrease of ~~$21.7~~$10.2 million due primarily to lower ~~net~~volumes as a result of severe winter weather in the first quarter of 2017;

a decrease of $2.4 million due primarily to lower realized ~~NGL,~~ natural gas ~~and condensate~~ prices; and

an increase of ~~$8.2~~$2.2 million in operating costs due primarily to increased labor and ~~materials and supplies related to the growth of ONEOK Partners’ operations resulting from completed capital-growth projects and~~ higher employee-related costs, ~~associated with incentive and medical benefit plans.~~

~~Adjusted EBITDA increased $98.9 million for the nine months ended September 30, 2016, compared with the same period in 2015, primarily as a result of the following:~~

~~an increase of $106.4 million due primarily to restructured contracts resulting in higher average fee rates,~~partially offset ~~partially~~ by a lower ~~percentage of proceeds retained from the sale of commodities under ONEOK Partners’ POP with fee contracts; and~~

~~an increase of $93.5 million due primarily to natural gas volume growth in the Williston Basin, offset partially by volume declines in the Mid-Continent region; offset partially by~~

~~a decrease of $80.2 million due primarily to lower net realized NGL and natural gas prices;~~

an increase of $14.5 million in operating costs due primarily to increased labor and materials and supplies related to the growth of ONEOK Partners’ operations resulting from completed capital-growth projects and higher employee-related costs associated with incentive and medical benefit plans;

~~a decrease of $5.5 million due to lower equity earnings primarily related to ONEOK Partners’ Powder River Basin equity investments; and~~

~~a decrease of $4.0 million due primarily to increased ethane recovery to maintain downstream NGL product specifications.~~outside service expenses.

Capital expenditures decreased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, due to projects placed in service in ~~2015, spending reductions to align with customer needs~~2016 and ~~lower~~fewer well ~~connect activities~~connections due to ~~a reduction~~the impact of severe winter weather in ~~drilling and completion activity.~~the Williston Basin in the first quarter 2017.

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

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


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
Operating Information (a)	2016		2015		2016		2015		2017		2016
Natural gas gathered (BBtu/d)	1,977		1,897		2,047		1,877		1,985		2,128
Natural gas processed (BBtu/d) (b)	1,829		1,617		1,886		1,640		1,863		1,948
NGL sales (MBbl/d)	153		134		155		123		172		155
Residue natural gas sales (BBtu/d)	837		837		877		828		793		941
Realized composite NGL net sales price ($/gallon) (c) (d)	$	0.23	$	0.31	$	0.22	$	0.35	$	0.19	$	0.20
Realized condensate net sales price ($/Bbl) (c) (e)	$	41.13	$	42.32	$	36.91	$	35.80	$	32.32	$	33.72
Realized residue natural gas net sales price ($/MMBtu) (c) (e)	$	2.84	$	3.62	$	2.76	$	3.64	$	2.38	$	2.62
Average fee rate ($/MMBtu)	$	0.76	$	0.43	$	0.73	$	0.39	$	0.83	$	0.68

(a) - Includes volumes for consolidated entities only.

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

(d) - Net of transportation and fractionation costs.

(e) - Net of transportation costs.

Natural gas gathered and natural gas processed ~~and NGL sales increased~~decreased during the three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015,~~2016, due to the ~~completion~~impact of ~~capital-growth projects~~severe winter weather in the ~~Williston Basin, offset partially by~~first quarter 2017 and natural ~~gas volume~~production declines ~~in the Mid-Continent region.~~

~~Natural gas gathered, natural gas processed,~~on existing wells. NGL sales increased and residue natural gas sales decreased due primarily to increased during the nine months ended September 30, 2016, compared with the same period in 2015, due to the completion of capital-growth projects in the Williston Basin, offset partially by weather events in the Williston Basin and natural gas volume declines in the Mid-Continent region.ethane recovery.

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


	Three Months Ended		Nine Months Ended		Three Months Ended
	September 30,		September 30,		March 31,
Equity Volume Information (a)	2016	2015	2016	2015	2017	2016

NGL sales - including ethane (MBbl/d)	13.6	24.9	15.3	21.0	9.8	16.4
Condensate sales (MBbl/d)	2.2	2.7	2.5	3.0	3.1	2.7
Residue natural gas sales (BBtu/d)	82.3	136.3	81.3	141.6	71.1	83.8

(a) - Includes volumes for consolidated entities only.

Equity NGL and natural gas volumes decreased during the three months ended March 31, 2017, compared with the same period in 2016, due to ONEOK Partners’ contract restructuring efforts and the impact of severe winter weather in the first quarter 2017. As contracts are renewed or restructured, ONEOK Partners has generally increased the fee component and lowered the percentage of proceeds that it retains from the sale of commodities.

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

Natural Gas Liquids

Overview - The Natural Gas Liquids segment owns and operates facilities that gather, fractionate, treat and distribute NGLs and store NGL products, primarily in Oklahoma, Kansas, Texas, New Mexico and the Rocky Mountain region where it provides ~~nondiscretionary~~midstream services to producers of NGLs and delivers those products to the two primary market centers, one in the Mid-Continent in Conway, Kansas, and the other in the Gulf Coast in Mont Belvieu, Texas. It owns or has an ownership interest in FERC-regulated natural gas liquids gathering and distribution pipelines in Oklahoma, Kansas, Texas, New Mexico, Montana, North Dakota, Wyoming and Colorado, and terminal and storage facilities in Missouri, Nebraska, Iowa and Illinois. ONEOK Partners also owns FERC-regulated natural gas liquids distribution and refined petroleum products pipelines in Kansas, Missouri, Nebraska, Iowa, Illinois and Indiana that connect its Mid-Continent assets with Midwest markets, including Chicago, Illinois. The majority of the pipeline-connected natural gas processing plants in Oklahoma, Kansas and the Texas Panhandle ~~which extract unfractionated NGLs from unprocessed natural gas,~~ are connected to its gathering systems. ONEOK Partners owns and operates truck- and rail-loading and -unloading facilities connected to its natural gas liquids fractionation ~~storage~~ and pipeline assets.

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

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

Exchange services - ONEOK ~~Partners’ exchange and storage services utilize~~Partners utilizes its assets to gather, fractionate and/or treat, and transport unfractionated NGLs, thereby converting them into marketable NGL products ~~that are stored and~~ shipped to a market center or customer-designated location. Many of these exchange volumes are under contracts with minimum volume commitments that provide a minimum level of revenues regardless of volumetric throughput. ~~Although~~ ONEOK Partners’ exchange services activities are primarily fee-based and include some rate-regulated tariffs; however, it also captures certain product price differentials asthrough the fractionation process.

~~volumes are fractionated.~~Transportation and storage services - ONEOK Partners transports NGL products and refined petroleum products, primarily under FERC-regulated tariffs. Tariffs specify the maximum rates ONEOK Partners may charge its customers and the general terms and conditions for NGL transportation service on its pipelines. ONEOK Partners’ storage activities consist primarily of fee-based NGL storage services at its Mid-Continent and Gulf Coast storage facilities.

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

~~ONEOK Partners’ optimization and marketing activities utilize~~utilizes its assets, contract portfolio and market knowledge to capture location, product and seasonal price differentials. It primarily transports NGL products between Conway, Kansas, and Mont Belvieu, Texas, to capture the location price differentials between the two market centers. ONEOK Partners’ marketing activities also include utilizing its natural gas liquids storage facilities to capture seasonal price differentials. A growing portion of ONEOK Partners’ marketing activities serves truck and rail markets. ONEOK Partners’ isomerization activities capture the price differential when normal butane is converted into the more valuable iso-butane at its isomerization unit in Conway, Kansas.

~~Excess NGL supply continues to result in narrow NGL location price differentials between~~Supply growth from the development of NGL-rich areas and capacity available on pipelines that connect the Mid-Continent and Gulf Coast resulted in NGL price differentials remaining narrow between the Mid-Continent market ~~centers.~~center at Conway, Kansas, and the Gulf Coast market center at Mont Belvieu, Texas. We expect these narrow price differentials to persist between ~~the Conway, Kansas, and Mont Belvieu, Texas,~~these two market centers ~~as a result of NGL production from various NGL-rich shale areas throughout the country,~~ until demand for NGLs increases from ~~petrochemicals~~petrochemical companies and exporters, which we anticipate to begin in the second half of 2017.

Supply growth has resulted in available ethane supplies that are greater than the petrochemical industry’s current demand. As a result, low or unprofitable price differentials between ethane and natural gas have resulted in ethane rejection at most of ONEOK Partners’ and its customers’ natural gas processing plants connected to its ~~natural gas liquids gathering~~NGL system in the Mid-Continent and Rocky Mountain regions, ~~during 2015 and 2016,~~ which reduced the ethane component of natural gas liquids volumes gathered, fractionated, transported and sold across ONEOK Partners’ assets. Through ethane rejection, natural gas processors leave ~~much~~some of the ethane component in the natural gas stream sold at the tailgate of natural gas processing plants. Ethane ~~rejection~~recovery levels by natural gas processors delivering to ONEOK Partners’ ~~natural gas liquids gathering~~NGL system have ~~continued to fluctuate and have~~increased, primarily in the Mid-Continent region. Ethane rejection levels across ONEOK Partners’ system averaged more than 150 MBbl/d in the first three months of 2017, compared with an average of more than 175 MBbl/d ~~during the first nine months of 2016, primarily~~ in the ~~Mid-Continent region.~~same period in 2016. While the volume of ethane recovered increased ~~modestly~~ during the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations. We expect ethane ~~rejection~~recovery levels ~~to continue~~ to fluctuate for the remainder of ~~2016~~2017 as ~~the market begins to balance~~ ethane supply and demand begin to balance and ~~with changes in~~as the price differentials between ethane and natural ~~gas.~~gas change. We expect ethane recovery levels to increase, first in regions closest to market centers, as ethylene producers and NGL exporters increase their capacity to consume and export additional ethane feedstock volumes. Ethane demand is expected to ramp up as new world-scale ethylene production projects, petrochemical plant modifications, plant expansions and export facilities near completion and begin coming on linevolumes in the second half of 2017.

Despite the ethane rejection across ONEOK Partners’ system, beginning in June 2015, the Natural Gas Gathering and Processing segment increased its level of ethane recovery in the Williston Basin to alleviate downstream NGL product specification issues, which offsets partially the financial impact of ethane rejection. We expect this increased ethane recovery to continue throughout 2016 and 2017. In addition, theThe Natural Gas Liquids segment’s integrated assets enable ONEOK Partners to mitigate partially the impact of ethane rejection through minimum volume commitments, contract modifications that vary fees for ethane and other NGL products, and ONEOK Partners’ ability to utilize the transportation capacity made available due to ethane rejection to capture additional NGL location price differentials, when they exist, in its optimization activities.

Growth Projects - ONEOK Partners’ growth strategy in the Natural Gas Liquids segment is focused around the crude oil and NGL-rich natural gas drilling activity in shale and other nonconventional resource areas from the Rocky Mountain region through the Mid-Continent region into Texas and New Mexico. Crude oil, natural gas and NGL production from this activity; higher petrochemical industry demand for NGL products; and increased exports have resulted in ONEOK Partners making additional capital investments to expand its infrastructure to bring these commodities from supply basins to market. ~~Expansion~~

The Natural Gas Liquids segment invests in NGL-related projects to accommodate the transportation, fractionation and storage of NGL supply from shale and other resource development areas across ONEOK Partners’ asset base, to alleviate expected infrastructure constraints between the Mid-Continent and Gulf Coast market centers and to meet increasing petrochemical industry and NGL export demand in the ~~United States is expected~~Gulf Coast.

ONEOK Partners connected three third-party natural gas processing plants to ~~increase ethane demand significantly beginning~~its NGL system in the first quarter 2017, one each in the Mid-Continent and ~~international demand for NGLs, particularly ethane~~Rocky Mountain regions and ~~propane, also is increasing.~~the Permian Basin. ONEOK Partners expects to connect two additional third-party natural gas processing plants in the Mid-Continent region and one additional third-party natural gas processing plant in the Permian Basin in the remainder of 2017.

In August 2016, ONEOK Partners completed the Bear Creek NGL infrastructure project in the Williston Basin, for approximately $45 million, excluding AFUDC.

~~In April 2015, ONEOK Partners completed~~Construction of Phase II of the Bakken NGL Pipeline expansion is planned for completion in the third quarter 2018, which is expected to increase capacity by 25 MBbl/d and ~~Hutchinson Fractionator infrastructure project for~~cost approximately ~~$120~~$100 million, excluding AFUDC.

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



~~Projects in Progress~~	~~Location~~	~~Capacity~~	~~Approximate~~ ~~Costs (a)~~	~~Expected~~ ~~Completion Date~~
			(~~In millions~~)
~~Bakken NGL Pipeline expansion - Phase II~~	~~Rocky Mountain Region~~	~~25 MBbl/d~~	~~$100~~	~~Third quarter 2018~~
~~Bronco NGL infrastructure~~	~~Powder River Basin~~	~~65 miles~~	~~$45-$60~~	~~Suspended~~
~~Demicks Lake NGL infrastructure~~	~~Williston Basin~~	~~12 miles~~	~~$10-$15~~	~~Suspended~~
~~Total~~			~~$155-$175~~

~~(a) - Excludes AFUDC.~~

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

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

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					Three Months Ended						Three Months
	September 30,						September 30,						2016 vs. 2015					2016 vs. 2015					March 31,						2017 vs. 2016
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)					2017			2016			Increase (Decrease)
	(Millions of dollars)																						(Millions of dollars)
NGL and condensate sales	$	1,649.6		$	1,253.1		$	4,264.1		$	3,965.2		$	396.5		32	%	$	298.9		8	%	$	2,008.0		$	1,117.1		$	890.9		80	%
Exchange service and storage revenues	346.4			313.2			1,004.0			861.8			33.2			11	%	142.2			17	%
Transportation revenues	43.3			45.1			130.5			129.4			(1.8		)	(4	%)	1.1			1	%
Exchange service revenues																							333.3			322.9			10.4			3	%
Transportation and storage revenues																							50.7			47.4			3.3			7	%
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(1,694.2		)	(1,289.6		)	(4,376.3		)	(4,054.0		)	404.6			31	%	322.3			8	%	(2,048.7		)	(1,157.0		)	891.7			77	%
Operating costs	(79.8		)	(74.5		)	(236.7		)	(234.1		)	5.3			7	%	2.6			1	%	(78.7		)	(73.2		)	5.5			8	%
Equity in net earnings from investments	14.0			10.9			41.2			27.6			3.1			28	%	13.6			49	%	13.7			13.3			0.4			3	%
Other	—			(2.5		)	(0.8		)	(2.9		)	2.5			100	%	2.1			72	%	(0.1		)	(0.3		)	0.2			67	%
Adjusted EBITDA	$	279.3		$	255.7		$	826.0		$	693.0		$	23.6		9	%	$	133.0		19	%	$	278.2		$	270.2		$	8.0		3	%
Capital expenditures	$	30.5		$	52.8		$	85.5		$	185.4		$	(22.3	)	(42	%)	$	(99.9	)	(54	%)	$	20.5		$	34.2		$	(13.7	)	(40	%)

See ~~Reconciliation~~reconciliation of ~~Adjusted~~net income to adjusted EBITDA ~~to Net Income~~ in the “Adjusted EBITDA” section.

Due to the nature of ONEOK Partners’ contracts, changes in commodity prices and sales volumes generally affect ~~commodity~~both NGL and condensate sales, and cost of sales and fuel, and ~~therefore~~ the impact is largely offset between these line items.

Adjusted EBITDA increased ~~$23.6~~$8.0 million for the three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015,~~2016, primarily as a result of the following:

an increase of ~~$22.9~~$5.3 million in ~~exchange,~~optimization and marketing due primarily to wider location price differentials;

an increase of $3.9 million in transportation and storage services ~~which includes:~~


◦	a $10.4 million increase due to increased exchange service volumes from recently connected natural gas processing plants primarily in the Williston Basin, offset partially by decreased Mid-Continent volumes gathered from the Barnett Shale and lower short-term contracted volumes;


◦	~~a $10.3 million increase from increased ethane recovery, which increased NGL exchange service volumes gathered and fractionated; and~~


◦	~~a $4.2 million increase related to higher storage activities; offset partially by~~


◦	~~a $1.8 million decrease in transportation revenues due primarily to lower volumes on West Texas Pipeline;~~

due to higher volumes on ONEOK Partners’ distribution pipelines and higher storage and terminaling revenue in the Gulf Coast region;

an increase of ~~$3.2~~$3.6 million ~~related~~due to ~~higher isomerization volumes, resulting from~~ wider ~~NGL~~ product price differentials, ~~between normal butane~~increased exchange service volumes from recently connected natural gas processing plants primarily in the Williston Basin, increased ethane recovery and ~~iso-butane;~~increased volumes gathered in the STACK and

~~an increase of $3.1 million in equity in net earnings~~ SCOOP areas, offset partially by decreased volumes gathered from ~~investments due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline;~~the Barnett Shale and lower rates on the West Texas LPG system; offset partially by

an increase of ~~$5.3~~$5.5 million in operating costs due primarily to higher ~~employee-related costs associated with incentive~~ad valorem taxes and ~~medical benefit plans; and~~

a decrease of $4.8 million in optimization and marketing activities, which resulted from a $5.9 million decrease due primarily to narrower marketing product price differentials, offset partially by a $1.1 million increase due primarily to higher optimization volumes.

~~Adjusted EBITDA increased $133.0 million for the nine months ended September 30, 2016, compared with the same period in 2015, primarily as a result of the following:~~

~~an increase of $114.9 million in exchange, transportation and storage services, which includes:~~


◦	a $53.8 million increase due to increased exchange service volumes from recently connected natural gas processing plants primarily in the Williston Basin, offset partially by decreased Mid-Continent volumes gathered from the Barnett Shale and lower short-term contracted volumes;


◦	~~a $49.0 million increase from increased ethane recovery, which increased NGL exchange service volumes gathered and fractionated; and~~


◦	~~a $7.2 million increase related to higher storage activities;~~

~~an increase of $13.6 million in equity in net earnings from investments due primarily to higher volumes delivered to Overland Pass Pipeline from ONEOK Partners’ Bakken NGL Pipeline; and~~

~~an increase of $4.0 million related to higher isomerization volumes, resulting from wider NGL product price differentials between normal butane and iso-butane; offset partially by~~

~~an increase of $2.6 million in operating costs due primarily to~~ higher employee-related costs primarily associated with incentive and medical benefit plans, offset partially by lower outside services costs due to lower rates charged by service providers and timing of ad valorem tax accruals.costs.

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				Three Months Ended
	September 30,				September 30,				March 31,
Operating Information	2016		2015		2016		2015		2017		2016
NGL sales (MBbl/d)	852		683		778		657
NGLs transported-gathering lines (MBbl/d) (a)	775		786		778		759		764		751
NGLs fractionated (MBbl/d) (b)	606		591		588		540		574		550
NGLs transported-distribution lines (MBbl/d) (a)	521		456		504		422		550		474
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.03	$	0.02	$	0.03	$	0.02	$	0.03	$	0.03

(a) - Includes volumes for consolidated entities only.

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

NGLs transported on gathering lines ~~decreased~~and NGLs fractionated increased for the three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in 2015, due to decreased volumes on the West Texas LPG system, decreased Mid-Continent volumes gathered from the Barnett Shale and lower short-term contracted volumes, offset partially by increased volumes from new plant connections primarily in the Williston Basin and increased ethane recovery.

~~NGLs transported on gathering lines increased for the nine months ended September 30,~~ 2016, ~~compared with the same period in 2015,~~ due to increased volumes from new plant connections primarily in the Williston Basin, ~~and~~ increased ethane recovery and increased Mid-Continent volumes gathered from the STACK and SCOOP areas. The increase in NGLs transported on gathering lines was offset partially by decreased volumes ~~on the West Texas LPG system, decreased Mid-Continent volumes~~ gathered from the Barnett ~~Shale and lower short-term contracted volumes.~~

NGLs fractionated increased for the three and nine months ended September 30, 2016, compared with the same periods in 2015, due primarily to increased volumes from new plant connections in the Williston Basin and increased ethane recovery.

Shale.

While the volume of ethane recovered increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, a portion of the fees associated with those volumes gathered and fractionated was previously being earned under contracts with minimum volume obligations.

NGLs transported on distribution lines increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, due primarily to higher fractionated volumes as discussed above and due to increased volumes transported for ONEOK Partners’ optimization activities.

Natural Gas Pipelines

Overview - The Natural Gas Pipelines segment provides transportation and storage services to end users through its wholly owned assets and its 50 percent ownership interests in Northern Border Pipeline and ~~its 50 percent ownership in~~ Roadrunner. ~~Phase I and Phase II of the Roadrunner pipeline were completed in March and October 2016, respectively.~~

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

Midwestern Gas Transmission, which is a bidirectional system that interconnects with Tennessee Gas Transmission Company’s pipeline near Portland, Tennessee, and with several interstate pipelines ~~at the Chicago Hub near Joliet, Illinois,~~ that have access to both the Utica Shale and the Marcellus ~~Shale;~~Shale at the Chicago Hub near Joliet, Illinois;

Viking Gas Transmission, which is a bidirectional system that interconnects with a TransCanada Corporation pipeline at the United States border near Emerson, Canada, and ANR Pipeline Company near Marshfield, Wisconsin;

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

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

Intrastate Pipelines - ONEOK Partners’ intrastate natural gas pipeline assets in Oklahoma transport natural gas through the state and have access to the major natural gas ~~producing formations, including~~production areas in the Mid-Continent region, which include the STACK and SCOOP areas in the Anadarko Basin and the Cana-Woodford Shale, Woodford Shale, Springer Shale, Meramec, Granite Wash and Mississippian ~~Lime.~~Lime formations. ONEOK Partners’ intrastate natural gas pipeline assets in Oklahoma serve end-use markets, such as local distribution companies and power generation companies. In Texas, ONEOK Partners’ intrastate natural gas pipelines are connected to the major natural gas producing formations in the Texas Panhandle, including the Granite Wash formation and ~~the~~ Delaware, Cline and ~~Cline~~Midland producing formations in the Permian Basin. These pipelines are capable of transporting natural gas throughout the western portion of Texas, including the Waha Hub where other pipelines may be accessed for transportation to western markets, exports to Mexico, the Houston Ship Channel market to the east and the Mid-Continent market to the north. ONEOK Partners’ intrastate natural gas pipeline assets also have access to the ~~natural gas producing formations~~Hugoton and Central Kansas Uplift Basins in ~~south central~~ Kansas.

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

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

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

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

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

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

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

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

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



~~Growth Projects~~	~~Location~~	~~Capacity~~	~~Approximate~~ ~~Costs (a)~~	~~Completion Date (c)~~
			(~~In millions~~)
~~WesTex pipeline expansion - Completed~~	~~Permian Basin~~	~~260 MMcf/d~~	~~$55~~	~~October 2016~~
~~Roadrunner Gas Transmission Pipeline - Equity-Method Investment~~
~~Phase I - Completed (b)~~	~~Permian Basin~~	~~170 MMcf/d~~	~~$200~~	~~March 2016~~
~~Phase II - Completed (b)~~	~~Permian Basin~~	~~400 MMcf/d~~	~~$210~~	~~October 2016~~
~~Phase III (b)~~	~~Permian Basin~~	~~70 MMcf/d~~	~~$30-$40~~	~~2019~~
~~Roadrunner Gas Transmission Pipeline Total~~			~~$440-$450~~

~~(a) - Excludes AFUDC.~~

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

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

WesTex ~~pipeline expansion~~Pipeline Expansion - In October 2016, the WesTex pipeline expansion was completed for approximately $55 million, excluding capitalized interest, ahead of original schedule and below cost estimates. This expansion increased the pipeline capacity by 260 MMcf/d.

Roadrunner - ~~In October 2016,~~Phase I and Phase II of the Roadrunner pipeline were completed in March and October 2016, respectively, for total project costs of approximately $200 million and $210 million, respectively, excluding capitalized interest. Phase II of Roadrunner was completed ahead of original schedule and below cost estimates. ~~This phase increased the pipeline’s~~The current capacity of Roadrunner is 570 MMcf/d. Construction of Phase III of Roadrunner is planned for completion in 2019, which is expected to increase capacity by ~~400~~70 MMcf/d and have total project costs of approximately $30 million to 570 MMcf/d. In 2015, Roadrunner entered into a $230 million senior secured credit facility for the construction and operation of the pipeline. The senior secured credit facility expires in the fourth quarter 2023. In addition, Roadrunner executed interest-rate swaps to hedge the variability of its interest payments during the term of the credit facility. Roadrunner’s credit facility is nonrecourse to ONEOK and $40 million.

ONEOK Partners ~~and neither ONEOK nor ONEOK Partners guarantees Roadrunner’s debts or obligations under the credit facility. ONEOK Partners contributed~~made contributions of approximately ~~$55~~$4.4 million to Roadrunner in the ~~nine~~three months ended ~~September 30,~~March 31, 2017. During the three months ended March 31, 2016, ~~and approximately $30 million in the year ended December 31, 2015.~~ ONEOK Partners ~~expects~~made no contributions to ~~contribute an additional $10 million to Roadrunner during the remainder of 2016.~~Roadrunner.

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


	Three Months Ended						Nine Months Ended						Three Months					Nine Months						Three Months Ended						Three Months
	September 30,						September 30,						2016 vs. 2015					2016 vs. 2015						March 31,						2017 vs. 2016
Financial Results	2016			2015			2016			2015			Increase (Decrease)					Increase (Decrease)						2017			2016			Increase (Decrease)
	(Millions of dollars)																						(Millions of dollars)
Transportation revenues	$	71.9		$	63.7		$	208.5		$	193.5		$	8.2		13	%	$	15.0		8	%		$	82.0		$	67.8		$	14.2		21	%
Storage revenues	13.3			14.2			44.0			42.4			(0.9		)	(6	%)	1.6			4	%		14.2			15.5			(1.3		)	(8	%)
Natural gas sales and other revenues	6.9			5.1			13.6			10.8			1.8			35	%	2.8			26	%		10.6			2.7			7.9			*
Cost of sales and fuel (exclusive of depreciation and items shown separately below)	(6.9		)	(7.6		)	(15.9		)	(28.1		)	(0.7		)	(9	%)	(12.2		)	(43	%)		(16.6		)	(3.9		)	12.7			*
Operating costs	(28.4		)	(26.7		)	(85.1		)	(79.1		)	1.7			6	%	6.0			8	%		(31.8		)	(27.5		)	4.3			16	%
Equity in net earnings from investments	18.6			17.0			51.2			52.1			1.6			9	%	(0.9		)	(2	%)		23.2			16.8			6.4			38	%
Other	4.9			(0.5		)	6.9			9.5			5.4			*		(2.6		)	(27	%)		1.4			2.9			(1.5		)	(52	%)
Adjusted EBITDA	$	80.3		$	65.2		$	223.2		$	201.1		$	15.1		23	%	$	22.1		11	%		$	83.0		$	74.3		$	8.7		12	%
Capital expenditures	$	24.5		$	14.7		$	71.7		$	39.9		$	9.8		67	%	$	31.8		80	%		$	25.0		$	17.9		$	7.1		40	%

* Percentage change is greater than 100 percent.

See ~~Reconciliation~~reconciliation of ~~Adjusted~~net income to adjusted EBITDA ~~to Net Income~~ in the “Adjusted EBITDA” section.

Due to the nature of ONEOK Partners’ business, changes in commodity prices and sales volumes affect natural gas sales and cost of sales and fuel and therefore the impact is largely offset between these line items.

Adjusted EBITDA increased ~~$15.1~~$8.7 million for the three months ended ~~September 30, 2016,~~March 31, 2017, compared with the same period in ~~2015,~~2016, primarily as a result of the following:

an increase of ~~$8.0~~$9.9 million from higher transportation services due primarily to increased firm demand charge ~~volumes contracted;~~contracted capacity; and

an increase of ~~$4.0~~$6.4 million in equity earnings due primarily to higher firm transportation revenues on Roadrunner; offset partially by

an increase of $4.3 million in operating costs due primarily to higher ad valorem taxes and employee-related costs; and

a decrease of $3.0 million due to ~~higher natural gas storage services primarily as a result of the sale~~gains on sales of excess natural gas in storage in ~~2016; and~~

~~an increase of $2.5 million from higher net retained fuel due primarily to higher throughput and~~ the ~~associated natural gas volumes retained; offset partially by~~

~~an increase of $1.7 million in operating costs due primarily to increased employee-related costs associated with incentive and medical benefit plans.~~

~~Adjusted EBITDA increased $22.1 million for the nine months ended September 30, 2016, compared with the same period in 2015, primarily as a result of the following:~~

~~an increase of $17.1 million from higher transportation services due primarily to increased firm demand charge volumes contracted;~~

~~an increase of $10.0 million due to higher natural gas storage services as a result of increased rates and the sale of excess natural gas in storage in 2016; and~~

~~an increase of $2.3 million from higher net retained fuel due to higher throughput and the associated natural gas volumes retained, offset partially by lower natural gas prices; offset partially by~~

~~an increase of $6.0 million in operating costs due primarily to increased employee-related costs associated with incentive and medical benefit plans.~~first quarter 2016.

Capital expenditures increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, compared with the same ~~periods~~period in ~~2015,~~2016, due primarily to the ~~WesTex pipeline expansion and other expansion~~timing of maintenance projects.

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


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
Operating Information (a)	2016			2015			2016			2015			2017			2016
Natural gas transportation capacity contracted (MDth/d)	6,300			5,739			6,240			5,797			6,757			6,156
Transportation capacity contracted	95		%	90		%	94		%	91		%
Transportation capacity subscribed													97		%	93		%
Average natural gas price
Mid-Continent region ($/MMBtu)	$	2.60		$	2.59		$	2.12		$	2.56		$	2.76		$	1.82

(a) - Includes volumes for consolidated entities only.

ONEOK Partners’ natural gas pipelines primarily serve end users, such as natural gas distribution and electric-generation companies, that require natural gas to operate their businesses regardless of location price differentials. The development of shale and other resource areas has continued to increase available natural gas supply, ~~resulting in narrower location~~ and ~~seasonal price differentials. As additional supply is developed,~~ ONEOK Partners expects ~~crude oil and natural gas~~ producers to demand incremental transportation services in the future ~~to transport their production to market.~~as additional supply is developed. The abundance of natural gas supply and ~~new~~ regulations on emissions from coal-fired electric-generation plants may also increase the demand for ONEOK Partners’ services from electric-generation companies as they convert to a natural gas fuel source. Overall, ONEOK ~~Partners expects its~~Partners’ contracted transportation capacity and fee-based earnings in this segment ~~to increase~~increased in connection with the October 2016 completion of ~~ONEOK Partners’~~its WesTex pipeline expansion.

Northern Border Pipeline, in which ONEOK Partners has a 50 percent ownership interest, has contracted substantially all of its long-haul transportation capacity through the first quarter 2018.

Roadrunner, in which ONEOK Partners has a 50 percent ownership interest, has contracted all of its capacity ~~for both Phase I and Phase II~~ through ~~the first quarter~~ 2041.

Adjusted EBITDA

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

A reconciliation of ~~Adjusted EBITDA for the three and nine months ended September 30, 2016 and 2015, to~~ net income, ~~which is~~ the nearest comparable GAAP financial performance measure, to adjusted EBITDA for the three months ended March 31, 2017 and 2016, is as follows:


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
(Unaudited)	2016			2015			2016			2015
Reconciliation of Adjusted EBITDA to Net Income	(Thousands of dollars)
Segment Adjusted EBITDA:
													2017			2016
Reconciliation of income from continuing operations to adjusted EBITDA													(Thousands of dollars)
Income from continuing operations													$	186,185		$	175,911
Add:
Interest expense, net of capitalized interest													116,462			118,247
Depreciation and amortization													99,419			94,478
Income taxes													54,941			50,066
Other noncash items and equity AFUDC													2,605			2,927
Adjusted EBITDA													$	459,612		$	441,629
Reconciliation of segment adjusted EBITDA to adjusted EBITDA
Segment adjusted EBITDA:
Natural Gas Gathering and Processing	$	109,837		$	82,718		$	320,170		$	221,298		$	103,967		$	100,035
Natural Gas Liquids	279,256			255,745			826,036			692,991			278,229			270,169
Natural Gas Pipelines	80,304			65,166			223,185			201,112			82,958			74,339
Total segment adjusted EBITDA													465,154			444,543
Other	(4,061		)	2,228			(9,744		)	(3,473		)	(5,542		)	(2,914		)
Total	465,336			405,857			1,359,647			1,111,928
Depreciation and amortization	(98,550		)	(88,299		)	(292,275		)	(261,241		)
Interest expense, net of capitalized interest	(118,240		)	(106,923		)	(355,463		)	(306,057		)
Income taxes	(55,012		)	(38,298		)	(157,536		)	(123,948		)
AFUDC and other	1,258			(7,639		)	(3,584		)	(9,127		)
Income from continuing operations	194,792			164,698			550,789			411,555
Income (loss) from discontinued operations, net of tax	(576		)	(3,860		)	(1,755		)	(4,144		)
Net income	$	194,216		$	160,838		$	549,034		$	407,411
Adjusted EBITDA													$	459,612		$	441,629

CONTINGENCIES

~~Gas Index Pricing Litigation~~ - See Part II, Item 1, Legal Proceedings, in this Quarterly Report for a discussion of developments concerning the Gas Pricing Index Litigation.

LIQUIDITY AND CAPITAL RESOURCES

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

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

not guarantee the debt or other similar commitments of ONEOK. Following the completion of the Merger Transaction described in Note B of the Notes to Consolidated Financial Statements in this Quarterly Report, we, ONEOK Partners and the Intermediate Partnership expect to issue guarantees, to the extent not already in place, of the indebtedness of ONEOK and ONEOK Partners.

ONEOK - ONEOK’s primary source of cash inflows are distributions to us from our general partner and limited partner interests in ONEOK Partners. The cash distributions that we expect to receive from ONEOK Partners are expected to provide sufficient resources to fund our operations, debt service and quarterly cash dividends. In addition, we incur certain costs on behalf of ONEOK Partners for which we are reimbursed. At ~~September 30, 2016,~~March 31, 2017, we had ~~$231.9~~approximately $302.3 million of cash on hand. Our next long-term debt maturity is in 2022.

Following the completion of the Merger Transaction with ONEOK Partners, the cash flow sources and requirements for ONEOK are expected to change significantly, as we will receive cash flows directly from operations and fund all capital expenditures. Additionally, we expect to have access to a significantly larger credit facility under the 2017 Credit Agreement. Our primary sources of cash inflows are expected to be from operating cash flows, commercial paper, bank credit facilities, debt issuances and the issuance of common stock. We expect ~~future~~these sources of cash ~~expenditures associated with~~flow to provide sufficient resources to finance our operations and quarterly cash dividends. ONEOK may access the ~~released transportation and storage capacity from the wind down of our former energy services business~~capital markets to ~~be approximately $21 million, with approximately $3 million to be paid in the remainder of 2016, $10 million~~issue debt or equity securities in 2017 ~~$4 million in 2018 and $4 million over the period 2019 through 2023.~~as it considers prudent to provide liquidity to refinance existing debt, improve credit metrics or for other corporate purposes.

ONEOK Partners - ONEOK Partners relies primarily on operating cash flows, commercial paper, bank credit facilities, debt issuances and the issuance of common units for its liquidity and capital resources requirements. As of September 30, 2016, ONEOK Partners had $5.5 million of cash on hand and available capacity under the ONEOK Partners Credit Agreement of $1.7 billion. In addition, in the first quarter 2016, ONEOK Partners drew the full $1.0 billion available under its Term Loan Agreement that matures in January 2019.

ONEOK Partners funds its operating expenses, debt service and cash distributions to its limited partners and general partner primarily with operating cash flows. To the extent operating cash flows are not sufficient to fund its cash distributions, ONEOK Partners may utilize short- and long-term debt and issuances of equity, as necessary. Capital expenditures are funded by operating cash flows, short- and long-term debt and issuances of equity. ONEOK Partners’ ability to continue to access capital markets for debt and equity financing under reasonable terms depends on its financial condition, credit ratings and market conditions. While lower commodity prices and industry uncertainty may result in increased financing costs, we believe ONEOK Partners ~~expects~~has secured sufficient access to ~~utilize~~the financial resources and liquidity necessary to meet its ~~commercial paper program, ONEOK Partners Credit Agreement, Term Loan Agreement~~requirements for working capital, debt service payments and capital expenditures. We believe that its available credit and cash ~~from operations~~and cash equivalents are adequate to ~~fund its announced capital-growth expenditures, refinance its senior notes maturities and~~ meet ~~its working capital needs through 2016 and well into 2017. However,~~liquidity requirements associated with commodity price volatility. ONEOK Partners may access the capital markets to issue debt or equity securities ~~prior to that time~~in 2017 as it considers prudent to provide liquidity for new capital projects, to refinance existing debt, to maintain investment-grade credit ratings or for other partnership purposes.

ONEOK Partners manages interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. For additional information on ONEOK Partners’ interest rate swaps, see Note D of the Notes to Consolidated Financial Statements in this Quarterly Report.

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

Short-term Liquidity - ONEOK’s sources of short-term liquidity are quarterly distributions from ONEOK Partners, cash on hand of ~~$231.9~~$302.3 million as of ~~September 30, 2016,~~March 31, 2017, and access to our $300 million ONEOK Credit Agreement. At ~~September 30, 2016,~~March 31, 2017, ONEOK had no short-term debt outstanding.

ONEOK Partners’ principal sources of short-term liquidity consist of cash generated from operating activities, distributions received from its equity-method investments and proceeds from its commercial paper program and the ONEOK Partners Credit Agreement.

In January 2016, ONEOK Partners extended the term of the ONEOK Partners Credit Agreement by one year to January 2020. The ONEOK Partners Credit Agreement is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. The ONEOK Partners Credit Agreement is

available for general partnership purposes, and based on its ~~“at-the-market” equity program.~~current credit ratings, borrowings, if any, will accrue interest at LIBOR plus 117.5 basis points. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership.

ONEOK Partners had working capital (defined as current assets less current liabilities) deficits of ~~$1.2~~$1.6 billion and ~~$697 million~~$1.7 billion as of ~~September 30, 2016,~~March 31, 2017, and December 31, ~~2015,~~2016, respectively. Although working capital is influenced by several factors, including, among other things, (i) the timing of (a) scheduled debt payments, (b) the collection and payment of accounts receivable and payable, and (c) equity and debt issuances, and (ii) the volume and cost of inventory and commodity imbalances, ONEOK Partners’ working capital deficit at ~~September 30,~~March 31, 2017, and at December 31, 2016, was driven primarily by ~~its~~ current maturities of long-term debt and ~~capital-growth projects. ONEOK Partners’ working capital deficit at December 31, 2015, was driven primarily by its capital-growth projects.~~short-term borrowings. ONEOK Partners may have working capital deficits in future periods as it continues to finance its capital-growth projects and repay long-term debt, often initially with short-term borrowings. ONEOK Partners’ decision to utilize short-term borrowings rather than long-term debt, due to more favorable interest rates, contributes to its working capital deficit. We do not expect ONEOK Partners’ working capital deficit to have an adverse impact to our or ONEOK Partners’ cash flows or operations. ~~Our~~The consolidated working capital balance is impacted primarily by ONEOK Partners’ working capital balance.

ONEOK Credit Agreement - In January 2016, we extended the term of our ONEOK Credit Agreement by one year to January 2020. At ~~September 30, 2016, ONEOK had $1.1 million of letters of credit issued and $298.9 million of credit available under the ONEOK Credit Agreement.~~

The ONEOK Credit Agreement is a $300 million revolving credit facility and contains certain financial, operational and legal covenants. At March 31, 2017, ONEOK had $1.1 million of letters of credit issued and $298.9 million of borrowing capacity under the ONEOK Credit Agreement.

ONEOK Partners Credit Agreement - At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners had ~~$694 million~~$1.3 billion of commercial paper outstanding, $14 million of letters of credit issued and no borrowings outstanding under the ONEOK Partners Credit Agreement. At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners had approximately ~~$5.5~~$8.5 million of cash and cash equivalents and approximately ~~$1.7~~$1.1 billion of ~~credit available~~borrowing capacity under the ONEOK Partners Credit Agreement.

2017 Credit Agreement - In ~~January 2016, ONEOK Partners extended~~April 2017, we entered into the ~~term~~2017 Credit Agreement with a syndicate of banks, effective upon the closing of the Merger Transaction described in Note B and the terminations of the existing ONEOK Credit Agreement and ONEOK Partners Credit ~~Agreement by one year to January 2020.~~Agreement. The ~~ONEOK Partners~~2017 Credit Agreement is a ~~$2.4~~$2.5 billion revolving credit facility and ~~includes a $100 million sublimit for the issuance of standby letters of credit~~contains certain financial, operational and a $150 million swingline sublimit. The ONEOK Partners Credit Agreement is available for general partnership purposes, and borrowings accrue interest at LIBOR plus 117.5 basis points. Amounts outstanding under ONEOK Partners’ commercial paper program reduce the borrowing capacity under the ONEOK Partners Credit Agreement. The ONEOK Partners Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership.legal covenants.

For additional information on the ONEOK Credit Agreement, ~~and~~ ONEOK Partners Credit Agreement and 2017 Credit Agreement, see Note DE of the Notes to Consolidated Financial Statements in this Quarterly Report.

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

Long-term Financing - In addition to our principal sources of short-term liquidity discussed above, we expect ONEOK Partners to fund its longer-term financing requirements by issuing common units or long-term notes. Other options to obtain financing include, but are not limited to, loans from financial institutions, issuance of convertible debt securities, asset securitization and the sale and lease-back of facilities.

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

investment-grade credit ratings, general financial condition, and expectations regarding its future earnings and projected cash flows, we expect ONEOK Partners will be able to meet its cash requirements and maintain investment-grade credit ratings.

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

~~ONEOK Partners Debt Issuances and Maturities~~ ~~- In January~~first quarter 2016, ONEOK Partners entered into the $1.0 billion ~~senior unsecured delayed-draw~~ Term Loan Agreement with a syndicate of ~~banks. During the first quarter 2016, ONEOK Partners~~banks and drew the full $1.0 billion available under the ~~agreement and~~agreement. ONEOK Partners used the proceeds to repay ~~its~~ $650 million ~~3.25 percent~~of senior notes, which matured in February 2016, to repay amounts outstanding under its commercial paper program and for general partnership purposes. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus ~~a margin that is~~130 basis points based ~~on the credit ratings assigned to ONEOK Partners’ senior, unsecured, long-term indebtedness. Based~~ on ONEOK Partners’ current ~~applicable~~ credit ~~rating, borrowings on the Term Loan Agreement will accrue at LIBOR plus 130 basis points.~~ratings. The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding, without penalty or premium, and contains substantially the same covenants as those contained in the ONEOK Partners Credit Agreement. In April 2017, ONEOK Partners entered into the first amendment to the Term Loan Agreement which, among

~~In October 2016,~~ other things, will add ONEOK as a guarantor to the Term Loan Agreement effective upon the closing of the Merger Transaction described in Note B.

ONEOK Partners ~~repaid~~expects to repay its ~~$450~~$400 million, ~~6.15~~2.0 percent senior notes due October 1, ~~2016,~~2017, with a combination of cash on hand and short-term borrowings.

For additional information on ONEOK Partners’ long-term debt, ~~including the Term Loan Agreement,~~ see Note E of the Notes to Consolidated Financial Statements in this Quarterly Report.

ONEOK Partners ~~Equity Issuances~~equity issuances - ONEOK Partners has an “at-the-market” equity program for the offer and sale from time to time of its common units, up to an aggregate amount of $650 million. The program allows ONEOK Partners to offer and sell its common units at prices it deems appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between ONEOK Partners and the sales agent. ONEOK Partners is under no obligation to offer and sell common units under the program. At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners had approximately $138 million of registered common units available for issuance through its “at-the-market” equity program.

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

ONEOK Partners manages interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. For additional information on ONEOK Partners’ interest rate swaps, see Note C of the Notes to Consolidated Financial Statements in this Quarterly Report.

Capital Expenditures - ONEOK Partners’ capital expenditures are financed typically through operating cash flows, short- and long-term debt and the issuance of equity. ONEOK Partners’ capital expenditures, excluding AFUDC and capitalized interest, were ~~$489.4~~$112.6 million and ~~$928.9~~$195.9 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015,~~ respectively.

The following table sets forth ONEOK Partners’ ~~2016~~2017 projected capital expenditures, excluding ~~acquisitions, contributions to its equity-method investments~~AFUDC and ~~AFUDC:~~capitalized interest:

2016 Projected Capital Expenditures

(Millions of dollars)
Natural Gas Gathering and Processing $ 340
Natural Gas Liquids 110
Natural Gas Pipelines 110
Other 10
Total projected capital expenditures $ 570



2017 Projected Capital Expenditures
		(Millions of dollars)
Natural Gas Gathering and Processing		$215-$260
Natural Gas Liquids		$215-$260
Natural Gas Pipelines		$80-$105
Other		$10-$15
Total projected capital expenditures		$520-$640

Credit Ratings - ONEOK and ONEOK Partners’ credit ratings as of April 24, 2017, are shown in the table below:



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

ONEOK Partners’ commercial paper program is rated Prime-2 by Moody’s and A-2 by S&P. In October 2016, Moody’s affirmed ONEOK Partners’ current credit ratings and revised its outlook to stable from ~~negative, citing~~negative. In December 2016, S&P affirmed ONEOK Partners’ ~~considerable reduction~~and our current credit ratings and revised the outlooks to stable from negative. In February 2017, in conjunction with the announcement of ~~commodity price risk~~the Merger Transaction with ONEOK Partners, S&P affirmed ONEOK Partners’ credit ratings and ~~focus on growth opportunities within its operating footprint.~~ outlook and placed our credit ratings under review for upgrade, while Moody’s placed ONEOK Partners’ credit ratings under review for downgrade and placed our credit ratings under review for upgrade.

ONEOK Partners’ credit ratings, which are investment-grade, may be affected by a material change in its financial ratios or a material event affecting its business and industry. The most common criteria for assessment of ONEOK Partners’ credit ratings are the debt-to-EBITDA ratio, interest coverage, business risk profile and liquidity.

~~Declines in the energy commodity price environment and its impact on ONEOK Partners’ results of operations and cash flows could cause the credit rating agencies to downgrade its credit ratings.~~ If ONEOK Partners’ credit ratings were downgraded, the cost to borrow funds under its ~~commercial paper program and~~Term Loan Agreement, the ONEOK Partners Credit Agreement and its commercial paper program would increase, and ONEOK Partners could potentially lose access to the commercial paper market. In the event that ONEOK Partners is unable to borrow funds under its commercial paper program and there has not been a material adverse change in its business, ONEOK Partners would continue to have access to the ONEOK Partners Credit Agreement, which expires in January 2020. An adverse credit rating change alone is not a default under the ONEOK Credit

Agreement or the ONEOK Partners Credit Agreement. A downgrade in ONEOK Partners’ credit ratings would likely result in a downgrade to ONEOK’s credit ratings. However, we would not expect a downgrade to our credit ratings to have a material impact on our results of operations.

In the normal course of business, ONEOK Partners’ counterparties provide secured and unsecured credit. In the event of a downgrade in ONEOK Partners’ credit ratings or a significant change in ONEOK Partners’ counterparties’ evaluation of its creditworthiness, ONEOK Partners could be required to provide additional collateral in the form of cash, letters of credit or other negotiable instruments as a condition of continuing to conduct business with such counterparties. ONEOK Partners may be required to fund margin requirements with its counterparties with cash, letters of credit or other negotiable instruments.

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

For the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016, ~~and the three months ended September 30, 2015,~~ ONEOK Partners’ cash ~~flow from operations~~distributions exceeded its cash distributions to its general partner and limited partners. ONEOK Partners’ cash flow from operations increased in the first nine months of 2016, compared with the same period in 2015, due primarily to contract restructuring in the Natural Gas Gathering and Processing segment and increased volumes in the Natural Gas Gathering and Processing and Natural Gas Liquids segments due to the completion of ONEOK Partners’ capital-growth projects and new plant connections. For the nine months ended September 30, 2015, ONEOK Partners’ cash distributions

~~exceeded its cash flow~~flows from operations and, as a result, ONEOK Partners utilized cash from operations, its commercial paper program and distributions received from its equity-method investments to fund ~~its~~ cash distributions, short-term liquidity needs and capital projects.

~~Energy Commodity Prices~~ ~~- Although ONEOK Partners is subject to some commodity price volatility, its commodity price exposure has been reduced~~ We expect increases in cash flows from operations in the remainder of 2017, compared with the first quarter of 2017, due primarily to ~~contract restructuring~~new plant connections, increased ethane recovery and new well connections that we expect will provide higher volumes in the Natural Gas Gathering and Processing ~~segment.~~and Natural Gas Liquids segments. ONEOK Partners ~~has~~ also ~~hedged a significant portion of~~experienced severe winter weather in the ~~Natural Gas Gathering and Processing segment’s commodity price risk for 2016 and~~Williston Basin in the first quarter 2017, ~~and has begun hedging commodity price risk for 2018. Significant fluctuations in commodity prices will affect its overall liquidity due to the~~which had an unfavorable impact ~~commodity price changes have~~ on its volumes and cash flows from operating activities, including the impact on working capital for NGLs and natural gas held in storage, margin requirements and certain energy-related receivables. While lower commodity prices and industry uncertainty may result in increased financing costs, we believe ONEOK Partners has secured sufficient access to the financial resources and liquidity necessary to meet its requirements for working capital, debt service payments and capital expenditures through 2016 and well into 2017. We believe that ONEOK Partners’ available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility. See Note C of the Notes to Consolidated Financial Statements and the discussion under “Commodity Price Risk” in Part I, Item 3, Quantitative and Qualitative Disclosures About Market Risk, in this Quarterly Report for information on ONEOK Partners’ hedging activities.operations.

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

CASH FLOW ANALYSIS

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

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


							Variances									Variances
	Nine Months Ended						2016 vs. 2015			Three Months Ended						2017 vs. 2016
	September 30,						Increase (Decrease)			March 31,						Favorable (Unfavorable)
	2016			2015						2017			2016
	(Millions of dollars)									(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	922.0		$	695.1		$	226.9		$	269.1		$	230.6		$	38.5
Investing activities	(484.6		)	(942.1		)	457.5			(109.5		)	(169.9		)	60.4
Financing activities	(297.4		)	112.7			(410.1		)	(97.7		)	(21.1		)	(76.6		)
Change in cash and cash equivalents	140.0			(134.3		)	274.3			61.9			39.6			22.3
Change in cash and cash equivalents included in discontinued operations	(0.2		)	(0.1		)	(0.1		)
Change in cash and cash equivalents from continuing operations	139.8			(134.4		)	274.2
Cash and cash equivalents at beginning of period	97.6			172.8			(75.2		)	248.9			97.6			151.3
Cash and cash equivalents at end of period	$	237.4		$	38.4		$	199.0		$	310.8		$	137.2		$	173.6

Operating Cash Flows - Operating cash flows are affected by earnings from our ~~and ONEOK Partners’~~ business activities. Changes in commodity prices and demand for ONEOK Partners’ services or products, whether because of general economic conditions, changes in

supply, changes in demand for the end products that are made with ONEOK Partners’ products or increased competition from other service providers, could affect our earnings and operating cash flows.

Cash flows from operating activities, before changes in operating assets and liabilities, were ~~$1.0 billion~~$339.8 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with ~~$814.9~~$331.9 million for the same period in ~~2015.~~2016. The increase is due primarily to higher ~~natural gas gathered and NGL volumes from ONEOK Partners’ completed capital-growth projects in the Natural Gas Gathering~~

~~and Processing and Natural Gas Liquids segments and higher~~ fees resulting from contract restructuring in ~~the~~ONEOK Partners’ Natural Gas Gathering and Processing segment, higher transportation services due to increased firm demand charge contracted capacity in ONEOK Partners’ Natural Gas Pipelines segment and increased optimization and marketing activities in ONEOK Partners’ Natural Gas Liquids segment resulting from wider location price differentials, offset partially by lower ~~commodity prices,~~volumes due to severe winter weather in ONEOK Partners’ Natural Gas Gathering and Processing segment as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows by ~~$112.7~~$70.7 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with a decrease of ~~$119.8~~$101.3 million for the same period in ~~2015.~~2016. This change is due primarily to the change in accounts receivable, accounts payable, and other accruals and deferrals resulting from the timing of receipt of cash from customers and payments to vendors, suppliers and other third ~~parties; and~~parties, the change in natural gas and NGLs in storage, which vary from period to period and vary with changes in commodity ~~prices.~~prices, and the change in risk-management assets and liabilities related to ONEOK Partners’ interest-rate swaps.

Investing Cash Flows - Cash used in investing activities decreased to ~~$484.6~~$109.5 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with ~~$942.1~~$169.9 million for the same period in ~~2015,~~2016, due primarily to ONEOK Partners’ ~~lower capital spending as a result of spending reductions to align with customer needs and~~ projects placed in service ~~higher proceeds received from ONEOK Partners’ sale~~in 2016 and fewer well connections in the Natural Gas Gathering and Processing segment due to the impact of ~~assets and higher distributions from ONEOK Partners’ unconsolidated affiliates, offset partially by higher contributions to ONEOK Partners’ Roadrunner joint venture.~~severe winter weather in the Williston Basin in the first quarter 2017.

Financing Cash Flows - Cash used in financing activities was ~~$297.4~~$97.7 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, compared with ~~cash provided by financing activities of $112.7~~$21.1 million for the ~~nine months ended September 30, 2015, a decrease of approximately $400 million.~~same period in 2016. The ~~decrease~~change was due primarily to ~~repayment~~the impact of ONEOK ~~Partners’ $650 million, 3.25 percent senior notes, which matured February 1, 2016. The remaining difference primarily relates~~Partners drawing on the Term Loan Agreement in the first quarter 2016 to ~~the net impact of changes in ONEOK Partners’ short-term borrowings and ONEOK Partners’ and our~~repay long-term debt and ~~equity issuances for the nine months ended September 30, 2016, compared with the same period in 2015, as described below.~~

During the nine months ended September 30, 2016, ONEOK Partners received long-term debt proceeds of $1.0 billion related to its Term Loan Agreement. During the nine months ended September 30, 2015, ONEOK Partners raised capital through debt and equity issuances from its March 2015 $800 million senior notes offering and approximately $375 million through its “at-the-market” equity program, respectively. During the nine months ended September 30, 2015, we received debt proceeds of approximately $500 million from our August 2015 senior notes offering. These items resulted in combined debt and equity proceeds for the nine months ended September 30, 2015, of approximately $1.7 billion. This decrease in financing cash inflow was offset by an increase of approximately $900 million in short-term borrowings ~~due to the net impact of borrowing and repayment activity in~~under ONEOK Partners’ commercial paper program.

REGULATORY, ENVIRONMENTAL AND SAFETY MATTERS

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

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

IMPACT OF NEW ACCOUNTING STANDARDS

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

ESTIMATES AND CRITICAL ACCOUNTING POLICIES

The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial

statements. These estimates and assumptions also affect the reported amounts of revenue and expenses during the reporting period. Although we believe these estimates and assumptions are reasonable, actual results could differ from our estimates.

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

FORWARD-LOOKING STATEMENTS

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

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

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

the ability to obtain the requisite approvals from our shareholders or ONEOK Partners’ unitholders relating to the Merger Transaction;

the risk that we or ONEOK Partners may be unable to obtain governmental and regulatory approvals required for the Merger Transaction, if any, or required governmental and regulatory approvals, if any, may delay the Merger Transaction or result in the imposition of conditions that could cause the parties to abandon the Merger Transaction;

the risk that a condition to closing of the Merger Transaction may not be satisfied;

the timing to consummate the Merger Transaction;

the risk that cost savings, tax benefits and any other synergies from the Merger Transaction may not be fully realized or may take longer to realize than expected;

disruption from the Merger Transaction may make it more difficult to maintain relationships with customers, employees or suppliers;

the possible diversion of management time on Merger Transaction-related issues;

the impact and outcome of pending and future litigation, including litigation, if any, relating to the Merger Transaction;

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;

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

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

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

the impact of unforeseen changes in interest rates, debt and 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 equity and bond market returns;

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

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

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

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

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

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

the impact and outcome of pending and future litigation;

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


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


–	competitive conditions in the overall energy market;


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


–	availability of additional storage capacity;

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

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

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

the mechanical integrity of facilities operated;

demand for our services in the proximity of our facilities;

our ability to control operating costs;

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

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

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

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

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

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

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

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

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

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

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

the impact of potential impairment charges;

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

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

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

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Part I, Item 1A, Risk Factors, in our most recent Annual Report on Form 10-K and in our other filings that we make with the SEC, which are available via the SEC’s website at www.sec.gov and our website at www.oneok.com. All forward-looking statements attributable to us or persons acting on our behalf are

expressly qualified in their entirety by these factors. Any such forward-looking statement speaks only as of the date on which such statement is made, and other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.


ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

COMMODITY PRICE RISK

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

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

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


	Three Months Ending December 31, 2016					Nine Months Ending December 31, 2017
	Volumes Hedged	Average Price			Percentage Hedged	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	8.8	$	0.48	/ gallon	83%	8.0	$	0.51	/ gallon	89%
Condensate (MBbl/d) - WTI-NYMEX	1.8	$	58.68	/ Bbl	79%	1.8	$	44.88	/ Bbl	78%
Natural gas (BBtu/d) - NYMEX and basis	77.8	$	2.82	/ MMBtu	93%	73.0	$	2.63	/ MMBtu	97%

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

Year Ending December 31, 2018
Volumes
Hedged Average Price Percentage
Hedged
Natural gas (BBtu/d) - NYMEX and basis
25.9
$ 2.83
/ MMBtu 32%



	Year Ending December 31, 2018
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	1.9	$	0.68	/ gallon	22%
Condensate (MBbl/d) - WTI-NYMEX	0.6	$	56.80	/ Bbl	25%
Natural gas (BBtu/d) - NYMEX and basis	49.7	$	2.80	/ MMBtu	74%

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, 2016.~~March 31, 2017. Condensate sales are typically based on the price of crude oil. We estimate the following for ONEOK Partners’ forecasted equity volumes, including the effects of hedging information set forth above, and assuming normal operating conditions:

a $0.01 per-gallon change in the composite price of NGLs would change adjusted EBITDA for the ~~three~~nine months ending December 31, ~~2016,~~2017, and for the year ending December 31, ~~2017,~~2018, by approximately ~~$0.2~~$0.3 million and ~~$1.0~~$1.9 million, respectively;

a $1.00 per-barrel change in the price of crude oil would change adjusted EBITDA for the ~~three~~nine months ending December 31, ~~2016,~~2017, and for the year ending December 31, ~~2017,~~2018, by approximately ~~$0.1~~$0.3 million and ~~$0.4~~$0.8 million, respectively; and

a $0.10 per-MMBtu change in the price of residue natural gas would change adjusted EBITDA for the ~~three~~nine months ~~ending December 31, 2016, for the year~~ ending December 31, 2017, and for the year ending December 31, 2018, by approximately $0.1 million ~~$0.9 million~~ and ~~$2.0~~$0.6 million respectively.

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

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

Three Months Ending December 31, 2016

Volumes
Hedged
Average Strike Price
Fair Value Asset at
September 30, 2016

(Millions of dollars)
Natural gas (BBtu/d) - NYMEX
232.8
$ 2.35
/ MMBtu $ 0.1

Year Ending December 31, 2017

Volumes
Hedged
Average Strike Price
Fair Value Asset at
September 30, 2016

(Millions of dollars)
Natural gas (BBtu/d) - NYMEX
147.9
$ 2.47
/ MMBtu $ 4.5



	Nine Months Ending December 31, 2017
	Volumes Hedged	Average Strike Price			Fair Value Asset at March 31, 2017
					(Millions of dollars)
Natural gas (BBtu/d) - NYMEX	147.3	$	2.47	/ MMBtu	$	0.8

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

INTEREST-RATE RISK

We and ONEOK Partners are exposed to interest-rate risk through the ONEOK Credit Agreement, ~~the~~ ONEOK Partners Credit Agreement, ONEOK Partners’ commercial paper program, Term Loan Agreement and long-term debt issuances. Future increases in LIBOR, corporate commercial paper rates or corporate bond rates could expose us and ONEOK Partners to increased interest costs on future borrowings. We and ONEOK Partners manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and interest-rate swaps. Interest-rate swaps are agreements to exchange interest payments at some future point based on specified notional amounts. As of ~~September 30,~~March 31, 2017, and December 31, 2016, ONEOK Partners had interest-rate swaps with notional amounts totaling ~~$1.0~~$1 billion to hedge the variability of ~~ONEOK Partners’~~our LIBOR-based interest ~~payments. In addition, in June 2016, ONEOK Partners entered into~~payments and forward-starting interest-rate swaps with notional amounts totaling ~~$750 million~~$1.2 billion to hedge the variability of interest payments on a portion of ~~its~~our forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is ~~issued, resulting in total notional amounts of this type of interest-rate swap of $1.2 billion at September 30, 2016, compared with $400 million at December 31, 2015.~~issued. All of ONEOK Partners’ interest-rate swaps are designated as cash flow hedges. At ~~September 30, 2016,~~March 31, 2017, ONEOK Partners had ~~$69.1~~derivative assets of $47.9 million ofand derivative liabilities of $11.3 million related to these interest-rate swaps. At December 31, ~~2015,~~2016, ONEOK Partners had derivative assets of $47.5 million and derivative liabilities of ~~$9.9~~$12.8 million related to these interest-rate swaps.

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

COUNTERPARTY CREDIT RISK

ONEOK and ONEOK Partners assess the creditworthiness of their respective counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. Certain of ONEOK Partners’ counterparties to the Natural Gas Gathering and Processing segment’s commodity sales, the Natural Gas Liquids segment’s marketing activities and the Natural Gas Pipelines segment’s storage activities may be impacted by the ~~depressed~~low commodity price environment and could experience financial problems, which could result in nonpayment and/or nonperformance, which could adversely impact our results of operations.

Customer concentration - For the three months ~~and nine months~~ ended ~~September 30, 2016 and 2015, we had~~March 31, 2017, no single customer ~~from which we received~~represented more than 10 percent ~~or more~~ of our consolidated revenues and only 2324 customers individually represented 1one percent or more of our consolidated revenues, the majority of which are investment-grade customers, as rated by S&P, or Moody’s or our comparable internal ratings, or secured by letters of credit or other collateral.

Natural Gas Gathering and Processing - The Natural Gas Gathering and Processing segment’s customers are crude oil and natural gas producers, which include both large integrated and independent exploration and production companies. ONEOK

Partners is not typically exposed to material credit risk with ~~exploration and production customers~~producers under POP with fee contracts as it ~~receives proceeds from~~sells the ~~sale of~~ commodities and remits a portion of ~~those~~the sales proceeds back to the ~~crude oil and natural gas producers.~~producer customer. For the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016, approximately 99 percent of the downstream commodity sales in the Natural Gas Gathering and Processing segment were made to investment-grade customers, as rated by S&P, or Moody’s or our comparable internal ratings, or were secured by letters of credit or other collateral.

Natural Gas Liquids - The Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies; large integrated and independent crude oil and natural gas production companies; propane distributors; ethanol producers; and petrochemical, refining and NGL marketing companies. ONEOK Partners earns fee-based revenue from NGL and natural gas gathering and processing customers and natural gas liquids pipeline transportation customers. ONEOK Partners is not typically exposed to material credit risk on the majority of its exchange services fee revenues, as ONEOK Partners purchases NGLs from its gathering and processing customers and deducts fees from the amounts it remits. ONEOK Partners also earns sales revenue on the downstream sales of NGL products. For the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016, approximately 8180 percent of this segment’s commodity sales were made to investment-grade customers, as rated by S&P, or Moody’s or our comparable internal ratings, or were secured by letters of credit or other collateral. In addition, the majority of the Natural Gas Liquids segment’s pipeline tariffs provide ONEOK Partners the ability to require security from shippers.

Natural Gas Pipelines - The Natural Gas Pipelines segment’s customers are primarily local natural gas distribution companies, electric-generation facilities, large industrial companies, municipalities, irrigation customers and marketing companies. For the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016, approximately 8785 percent of the revenues in this segment were from investment-grade customers, as rated by S&P, or Moody’s or our comparable internal ratings, or were secured by letters of credit or other collateral. In addition, the majority of the Natural Gas ~~Pipeline~~Pipelines segment’s pipeline tariffs provide ONEOK Partners the ability to require security from shippers.


ITEM 4.	CONTROLS AND PROCEDURES

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

Changes in Internal Control Over Financial Reporting - There have been no changes in our internal control over financial reporting during the quarter ended ~~September 30, 2016~~March 31, 2017, 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

~~In October 2016, we reached an agreement in principle to settle~~Gas Index Pricing Litigation - On March 30, 2017, the ~~claims alleged against us and our affiliate ONEOK Energy Services Company, L.P., (“OESC”) in~~ ~~Reorganized FLI, Inc.~~ ~~(formerly~~ ~~J.P. Morgan Trust Company~~) ~~v. ONEOK, Inc., et al.~~ ~~(filed in the District~~ Court ~~of Wyandotte County, Kansas, in October 2005, transferred to MDL 166 in the United States District Court for the District of Nevada (“the Court”). We previously reported that the Court had~~ entered an order granting summary judgment in favor of our ~~favor~~affiliate OESC, the lone defendant in this case in our Quarterly Report for the second quarter 2016. The amount we expect to pay to settle this case is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

~~et al.~~ ~~(filed in the District Court of Wyandotte, Kansas, in November 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada);~~ ~~Arandell Corporation, et al. v. Xcel Energy, Inc., et al.~~ ~~(filed in the Circuit Court for Dane County, Wisconsin, in December 2006, transferred to MDL-1566 in the United States District Court for the District of Nevada);~~ ~~Heartland Regional Medical Center, et al. v. ONEOK, Inc., et al.~~ ~~(filed in the Circuit Court of Buchanan County, Missouri, in March 2007, transferred to MDL-1566 in the United States District Court for the District of Nevada); and~~ ~~NewPage Wisconsin System v. CMS Energy Resource Management Company, et al.~~ (filed in the Circuit Court for Wood County, Wisconsin, in March 2009, transferred to MDL-1566 in the United States District Court for the District of Nevada and now consolidated with the Arandell case). We initially reported this agreement in principle in our Quarterly Report for the first quarter 2016. The amount we expect to pay to settle these cases is not material to our results of operations, financial position or cash flows and is expected to be paid with cash on hand.

~~The above agreements in principle to settle do not apply to~~ Sinclair Oil Corporation v. ONEOK Energy Services ~~Corporation, L.P., et al.~~ Company, L.P~~(filed~~. (filed in the United States District Court for the District of Wyoming in September 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada). ~~We expect~~The Court determined that ~~future charges, if any, from~~ the ~~ultimate resolution~~plaintiff’s claim is barred by a release obtained in a prior lawsuit against us and OESC. Upon entry of a final judgment, Sinclair Oil Corporation may pursue an appeal of this ~~matter will not be material~~determination to ~~our results~~the Ninth Circuit Court of ~~operations, financial position or cash flows.~~Appeals.

Additional information about our legal proceedings is included in Note L of the Notes to Consolidated Financial Statements in this Quarterly Report and under Part I, Item 3, Legal Proceedings, in our Annual Report.


ITEM 1A.	RISK FACTORS

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


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

~~Not applicable.~~In April 2017, through a wholly owned subsidiary, we contributed 20,000 shares of newly issued Series E Preferred Stock, par value $0.01 per share, having an aggregate value of $20 million, to ONEOK Foundation, Inc. for use in future charitable and nonprofit causes. The shares of Series E Preferred Stock were issued by us pursuant to Section 4(a)(2) of the Securities Act of 1933, as amended, in a transaction not involving a public offering. The Series E Preferred Stock may not be re-offered or sold in the United States absent an effective registration statement or an exemption from the registration requirements under applicable federal and state securities laws.


ITEM 3.	DEFAULTS UPON SENIOR SECURITIES

Not applicable.


ITEM 4.	MINE SAFETY DISCLOSURES

Not applicable.


ITEM 5.	OTHER INFORMATION

Not applicable.


ITEM 6.	EXHIBITS

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

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


Exhibit No.	Exhibit Description


2.1	Agreement and Plan of Merger, dated as of January 31, 2017, by and among ONEOK, Inc., New Holdings Subsidiary, LLC, ONEOK Partners, L.P. and ONEOK Partners GP, L.L.C. (incorporated by reference from Exhibit 2.1 to ONEOK Inc.’s Current Report on Form 8-K filed February 1, 2017 (File No. 1-13643)).


3.1	Amended and Restated By-laws of ONEOK, Inc. (incorporated by reference from Exhibit 3.1 to ONEOK Inc.’s Current Report on Form 8-K filed February 22, 2017 (File No. 1-13643)).


3.2	Amended and Restated Certificate of Incorporation of ONEOK, Inc., dated May 15, 2008, as amended.


10.1	Form of 2017 Restricted Unit Award Agreement dated February 22, 2017 (incorporated by reference from Exhibit 10.19 to ONEOK Inc.’s Annual Report on Form 10-K filed February 28, 2017 (File No. 1-13643)).


10.2	Form of 2017 Performance Unit Award Agreement dated February 22, 2017 (incorporated by reference from Exhibit 10.20 to ONEOK Inc.’s Annual Report on Form 10-K filed February 28, 2017 (File No. 1-13643)).


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, 2016~~March 31, 2017 and ~~2015~~2016; (iii) Consolidated Statements of Comprehensive Income for the three ~~and nine~~ months ended ~~September 30, 2016~~March 31, 2017 and ~~2015~~2016; (iv) Consolidated Balance Sheets at ~~September 30, 2016~~March 31, 2017, and December 31, ~~2015~~2016; (v) Consolidated Statements of Cash Flows for the ~~nine~~three months ended ~~September 30, 2016~~March 31, 2017 and ~~2015~~2016; (vi) Consolidated Statements of Changes in Equity for the ~~nine~~three months ended ~~September 30, 2016~~March 31, 2017 and ~~2015;~~2016; 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.

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 2, 2016~~May 3, 2017	By:	/s/ Derek S. Reiners
		Derek S. Reiners
		Senior Vice President,
		Chief Financial Officer and Treasurer
		(Principal Financial Officer)

6558



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



	Nine Months Ended September 30, 2016
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS from continuing operations
Income from continuing operations attributable to ONEOK available for common stock	$	263,289	211,038	$	1.25
Diluted EPS from continuing operations
Effect of dilutive securities	—		1,085
Income from continuing operations attributable to ONEOK available for common stock and common stock equivalents	$	263,289	212,123	$	1.24



Nine Months Ended September 30, 2016	Natural Gas Gathering and Processing			Natural Gas Liquids (a)			Natural Gas Pipelines (b)			Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	971,834		$	5,030,820		$	262,276		$	1,543		$	6,266,473
Intersegment revenues	449,154			367,820			3,843			(820,817		)	—
Total revenues	1,420,988			5,398,640			266,119			(819,274		)	6,266,473
Cost of sales and fuel (exclusive of items shown separately below)	902,747			4,376,345			15,914			(820,352		)	4,474,654
Operating costs	208,353			236,722			85,075			22,855			553,005
Depreciation and amortization	133,258			122,153			34,634			2,230			292,275
(Gain) loss on sale of assets	(2,331		)	(12		)	(7,133		)	(61		)	(9,537		)
Operating income	$	178,961		$	663,432		$	137,629		$	(23,946	)	$	956,076
Equity in net earnings from investments	$	7,987		$	41,211		$	51,243		$	—		$	100,441
Investments in unconsolidated affiliates	$	68,735		$	470,635		$	404,020		$	—		$	943,390
Total assets	$	5,268,161		$	8,257,203		$	1,912,951		$	543,720		$	15,982,035
Noncontrolling interests in consolidated subsidiaries	$	—		$	158,352		$	—		$	3,067,566		$	3,225,918
Capital expenditures	$	325,820		$	85,519		$	71,721		$	8,468		$	491,528



Nine Months Ended September 30, 2015	Natural Gas Gathering and Processing			Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Other and Eliminations			Total
	(Thousands of dollars)
Sales to unaffiliated customers	$	862,462		$	4,726,617	$	241,605	$	1,620		$	5,832,304
Intersegment revenues	487,559			229,804		5,053		(722,416		)	—
Total revenues	1,350,021			4,956,421		246,658		(720,796		)	5,832,304
Cost of sales and fuel (exclusive of items shown separately below)	947,539			4,054,039		28,059		(721,871		)	4,307,766
Operating costs	193,922			234,120		79,156		1,347			508,545
Depreciation and amortization	109,035			118,044		32,484		1,678			261,241
(Gain) loss on sale of assets	(328		)	579		76		283			610
Operating income	$	99,853		$	549,639	$	106,883	$	(2,233	)	$	754,142
Equity in net earnings from investments	$	13,511		$	27,585	$	52,109	$	—		$	93,205
Investments in unconsolidated affiliates	$	253,548		$	484,403	$	399,108	$	—		$	1,137,059
Total assets	$	5,206,987		$	8,041,064	$	1,845,232	$	415,015		$	15,508,298
Noncontrolling interests in consolidated subsidiaries	$	4,066		$	161,210	$	—	$	3,457,557		$	3,622,833
Capital expenditures	$	692,570		$	185,360	$	39,923	$	12,463		$	930,316



2016 Projected Capital Expenditures
	(Millions of dollars)
Natural Gas Gathering and Processing	$	340
Natural Gas Liquids	110
Natural Gas Pipelines	110
Other	10
Total projected capital expenditures	$	570



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