10-Q

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2020.

OR

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

For the transition period from __________ to __________.

Commission file number   001-13643

ONEOK, Inc.

(Exact name of registrant as specified in its charter)

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

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

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

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common stock, par value of $0.01	OKE	New York Stock Exchange

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 ☒  No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files). Yes ☒  No ☐

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

Large Accelerated Filer ☒  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 ☒

On October 19, 2020, the Company had 444,397,414 shares of common stock outstanding.

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ONEOK, Inc.

TABLE OF CONTENTS

Part I.	Financial Information	Page No.
Item 1.	Financial Statements (Unaudited)	6
	Consolidated Statements of Income - Three and Nine Months Ended September 30, 2020 and 2019	6
	Consolidated Statements of Comprehensive Income - Three and Nine Months Ended September 30, 2020 and 2019	7
	Consolidated Balance Sheets - September 30, 2020, and December 31, 2019	8
	Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2020 and 2019	11
	Consolidated Statements of Changes in Equity - Three and Nine Months Ended September 30, 2020 and 2019	12
	Notes to Consolidated Financial Statements	16
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	53
Item 4.	Controls and Procedures	55
Part II.	Other Information	55
Item 1.	Legal Proceedings	55
Item 1A.	Risk Factors	55
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	56
Item 3.	Defaults Upon Senior Securities	56
Item 4.	Mine Safety Disclosures	56
Item 5.	Other Information	56
Item 6.	Exhibits	56
Signature		58

As used in this Quarterly Report, references to “we,” “our” or “us” refer to ONEOK, Inc., an Oklahoma corporation, and its predecessors 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,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “guidance,” “intend,” “may,” “might,” “outlook,” “plan,” “potential,” “project,” “scheduled,” “should,” “will,” “would” 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,” and Part II, Item 1A, “Risk Factors,” in this Quarterly Report and under Part I, Item 1A, “Risk Factors,” in our Annual Report.

INFORMATION AVAILABLE ON OUR WEBSITE

We make available, free of charge, on our website (www.oneok.com) copies of our Annual Reports, Quarterly Reports, Current Reports on Form 8-K, amendments to those reports filed or furnished to the SEC pursuant to Section 13(a) or 15(d) of the Exchange Act and reports of holdings of our securities filed by our officers and directors under Section 16 of the Exchange Act as soon as reasonably practicable after filing such material electronically or otherwise furnishing it to the SEC. Copies of our Code of Business Conduct and Ethics, Corporate Governance Guidelines, Director Independence Guidelines, Corporate Sustainability Report, Response to COVID-19 and the written charter of our Audit Committee also are available on our website, and we will provide copies of these documents upon request.

In addition to our filings with the SEC and materials posted on our website, we also use social media platforms as additional channels of distribution to reach public investors. Information contained on our website, posted on our social media accounts, and any corresponding applications, are not incorporated by reference into this report.

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GLOSSARY

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

$1.5 Billion Term Loan Agreement	The senior unsecured delayed-draw three-year $1.5 billion term loan agreement dated November 19, 2018
$2.5 Billion Credit Agreement	ONEOK’s $2.5 billion revolving credit agreement, as amended
AFUDC	Allowance for funds used during construction
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2019
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
CARES Act	Coronavirus Aid, Relief, and Economic Security Act
CFTC	U.S. Commodity Futures Trading Commission
Clean Air Act	Federal Clean Air Act, as amended
COVID-19	Coronavirus disease 2019
DJ	Denver-Julesburg
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
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the United States of America
Intermediate Partnership	ONEOK Partners Intermediate Limited Partnership, a wholly owned subsidiary of ONEOK Partners, L.P.
LIBOR	London Interbank Offered Rate
MBbl/d	Thousand barrels per day
MDth/d	Thousand dekatherms per day
MMBbl	Million barrels
MMBbl/d	Million barrels per day
MMBtu	Million British thermal units
MMcf/d	Million cubic feet per day
Moody’s	Moody’s Investors Service, Inc.
Natural Gas Act	Natural Gas Act of 1938, as amended
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
Northern Border Pipeline	Northern Border Pipeline Company, a 50% owned joint venture
NYMEX	New York Mercantile Exchange
ONEOK	ONEOK, Inc.
ONEOK Partners	ONEOK Partners, L.P.
OPIS	Oil Price Information Service
Overland Pass Pipeline	Overland Pass Pipeline Company, LLC, a 50% owned joint venture
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 50% owned joint venture
S&P	S&P Global Ratings
SEC	Securities and Exchange Commission
Series E Preferred Stock	Series E Non-Voting, Perpetual Preferred Stock, par value $0.01 per share
STACK	Sooner Trend Anadarko Canadian Kingfisher, an area in the Anadarko Basin in Oklahoma
West Texas LPG	West Texas LPG pipeline and Mesquite pipeline
WTI	West Texas Intermediate
XBRL	eXtensible Business Reporting Language

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PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(Unaudited)	2020		2019		2020		2019
	(Thousands of dollars, except per share amounts)
Revenues
Commodity sales	$	1,852,198	$	1,947,834	$	5,004,375	$	6,567,634
Services	322,066		315,394		967,290		933,127
Total revenues (Note L)	2,174,264		2,263,228		5,971,665		7,500,761
Cost of sales and fuel (exclusive of items shown separately below)	1,265,674		1,414,528		3,483,060		4,996,699
Operations and maintenance	173,548		218,305		538,782		632,332
Depreciation and amortization	153,245		121,430		426,014		350,552
Impairment charges (Note A)	—		—		604,024		—
General taxes	31,381		26,830		97,651		91,257
(Gain) loss on sale of assets	(17)		(16)		(560)		2,882
Operating income	550,433		482,151		822,694		1,427,039
Equity in net earnings from investments (Note I)	38,046		37,576		108,001		115,175
Impairment of equity investments (Note A)	—		—		(37,730)		—
Allowance for equity funds used during construction	3,084		15,792		22,347		45,175
Other income	8,175		6,643		34,390		21,685
Other expense	(4,496)		(6,065)		(14,667)		(14,024)
Interest expense (net of capitalized interest of $13,821, $27,610, $61,439 and $73,601, respectively)	(176,371)		(129,577)		(535,955)		(362,490)
Income before income taxes	418,871		406,520		399,080		1,232,560
Income taxes	(106,555)		(97,365)		(94,300)		(274,234)
Net income	312,316		309,155		304,780		958,326
Less: Preferred stock dividends	275		275		825		825
Net income available to common shareholders	$	312,041	$	308,880	$	303,955	$	957,501
Basic earnings per common share (Note G)	$	0.70	$	0.75	$	0.71	$	2.32
Diluted earnings per common share (Note G)	$	0.70	$	0.74	$	0.71	$	2.31
Average shares (thousands)
Basic	445,103		413,816		426,369		413,443
Diluted	445,510		415,578		426,997		415,277

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(Unaudited)	2020		2019		2020		2019
	(Thousands of dollars)
Net income	$	312,316	$	309,155	$	304,780	$	958,326
Other comprehensive income (loss), net of tax
Change in fair value of derivatives, net of tax of $4,704, $22,050, $50,307 and $59,679, respectively	(15,750)		(73,822)		(168,421)		(199,795)
Derivative amounts reclassified to net income, net of tax of $(3,038), $2,673, $(3,360) and $8,654, respectively	5,361		(8,952)		11,210		(29,748)
Change in retirement and other postretirement benefit plan obligations, net of tax of $(1,064), $(737), $(3,192) and $(2,172), respectively	3,562		2,465		10,685		7,271
Other comprehensive income (loss) of unconsolidated affiliates, net of tax of $(332), $1,314, $3,015 and $3,164, respectively	1,112		(4,399)		(10,092)		(10,593)
Total other comprehensive loss, net of tax	(5,715)		(84,708)		(156,618)		(232,865)
Comprehensive income	$	306,601	$	224,447	$	148,162	$	725,461

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
	September 30,		December 31,
(Unaudited)	2020		2019
Assets	(Thousands of dollars)
Current assets
Cash and cash equivalents	$	447,129	$	20,958
Accounts receivable, net	717,852		835,121
Materials and supplies	158,950		201,749
NGLs and natural gas in storage	300,577		304,926
Commodity imbalances	13,289		25,267
Other current assets	83,565		82,313
Total current assets	1,721,362		1,470,334
Property, plant and equipment
Property, plant and equipment	22,803,167		22,051,492
Accumulated depreciation and amortization	3,773,852		3,702,807
Net property, plant and equipment	19,029,315		18,348,685
Investments and other assets
Investments in unconsolidated affiliates (Note A)	790,373		861,844
Goodwill and intangible assets (Note A)	776,330		957,833
Other assets	463,496		173,425
Total investments and other assets	2,030,199		1,993,102
Total assets	$	22,780,876	$	21,812,121

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(Continued)
	September 30,		December 31,
(Unaudited)	2020		2019
Liabilities and equity	(Thousands of dollars)
Current liabilities
Current maturities of long-term debt (Note D)	$	7,650	$	7,650
Short-term borrowings (Note D)	—		220,000
Accounts payable	624,483		1,209,900
Commodity imbalances	125,955		104,480
Accrued taxes	103,778		75,422
Accrued interest	140,506		190,750
Operating lease liability (Note K)	13,646		1,883
Other current liabilities	78,124		210,213
Total current liabilities	1,094,142		2,020,298
Long-term debt, excluding current maturities (Note D)	14,249,339		12,479,757
Deferred credits and other liabilities
Deferred income taxes	582,334		536,063
Operating lease liability (Note K)	90,806		13,509
Other deferred credits	618,143		536,543
Total deferred credits and other liabilities	1,291,283		1,086,115
Commitments and contingencies (Note J)
Equity (Note E)
ONEOK shareholders’ equity:
Preferred stock, $0.01 par value: authorized and issued 20,000 shares at September 30, 2020, and December 31, 2019	—		—
Common stock, $0.01 par value: authorized 1,200,000,000 shares, issued 474,916,234 shares and outstanding 444,392,615 shares at September 30, 2020; issued 445,016,234 shares and outstanding 413,239,050 shares at December 31, 2019	4,749		4,450
Paid-in capital	7,448,484		7,403,895
Accumulated other comprehensive loss (Note F)	(530,618)		(374,000)
Retained earnings	—		—
Treasury stock, at cost: 30,523,619 shares at September 30, 2020, and 31,777,184 shares at December 31, 2019	(776,503)		(808,394)
Total equity	6,146,112		6,225,951
Total liabilities and equity	$	22,780,876	$	21,812,121

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Nine Months Ended
	September 30,
(Unaudited)	2020		2019
	(Thousands of dollars)
Operating activities
Net income	$	304,780	$	958,326
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	426,014		350,552
Impairment charges	641,754		—
Equity in net earnings from investments	(108,001)		(115,175)
Distributions received from unconsolidated affiliates	109,595		121,176
Deferred income tax expense	93,174		269,488
Other, net	(17,599)		(18,337)
Changes in assets and liabilities:
Accounts receivable	111,629		100,250
NGLs and natural gas in storage	4,349		13,122
Accounts payable	(198,809)		(162,806)
Accrued interest	(50,244)		(39,314)
Risk-management assets and liabilities	(136,543)		(93,244)
Other assets and liabilities, net	(76,971)		(57,193)
Cash provided by operating activities	1,103,128		1,326,845
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(1,924,003)		(2,739,338)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	22,280		82,171
Other, net	(80,148)		9,293
Cash used in investing activities	(1,981,871)		(2,647,874)
Financing activities
Dividends paid	(1,189,575)		(1,079,379)
Repayment of short-term borrowings, net	(220,000)		—
Issuance of long-term debt, net of discounts	3,244,777		4,185,435
Debt financing costs	(28,324)		(29,777)
Repayment of long-term debt	(1,433,480)		(1,055,436)
Issuance of common stock	959,653		19,333
Other	(28,137)		(57,813)
Cash provided by financing activities	1,304,914		1,982,363
Change in cash and cash equivalents	426,171		661,334
Cash and cash equivalents at beginning of period	20,958		11,975
Cash and cash equivalents at end of period	$	447,129	$	673,309

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Unaudited)	Common Stock Issued	Preferred Stock Issued	Common Stock		Preferred Stock		Paid-in Capital
	(Shares)		(Thousands of dollars)
January 1, 2020	445,016,234	20,000	$	4,450	$	—	$	7,403,895
Net loss	—	—	—		—		—
Other comprehensive loss (Note F)	—	—	—		—		—
Preferred stock dividends - $13.75 per share (Note E)	—	—	—		—		(275)
Common stock issued	—	—	—		—		(9,286)
Common stock dividends - $0.935 per share (Note E)	—	—	—		—		(386,931)
Other, net	—	—	—		—		(17,950)
March 31, 2020	445,016,234	20,000	$	4,450	$	—	$	6,989,453
Net income	—	—	—		—		—
Other comprehensive loss (Note F)	—	—	—		—		—
Preferred stock dividends - $13.75 per share (Note E)	—	—	—		—		(275)
Common stock issued	29,900,000	—	299		—		939,038
Common stock dividends - $0.935 per share (Note E)	—	—	—		—		(387,037)
Other, net	—	—	—		—		8,652
June 30, 2020	474,916,234	20,000	$	4,749	$	—	$	7,549,831
Net income	—	—	—		—		—
Other comprehensive loss (Note F)	—	—	—		—		—
Preferred stock dividends - $13.75 per share (Note E)	—	—	—		—		—
Common stock issued	—	—	—		—		803
Common stock dividends - $0.935 per share (Note E)	—	—	—		—		(110,948)
Other, net	—	—	—		—		8,798
September 30, 2020	474,916,234	20,000	$	4,749	$	—	$	7,448,484

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Continued)
(Unaudited)	Accumulated Other Comprehensive Loss		Retained Earnings (Accumulated Deficit)		Treasury Stock		Total Equity
	(Thousands of dollars)
January 1, 2020	$	(374,000)	$	—	$	(808,394)	$	6,225,951
Net loss	—		(141,857)		—		(141,857)
Other comprehensive loss (Note F)	(125,386)		—		—		(125,386)
Preferred stock dividends - $13.75 per share (Note E)	—		—		—		(275)
Common stock issued	—		—		16,375		7,089
Common stock dividends - $0.935 per share (Note E)	—		—		—		(386,931)
Other, net	—		—		—		(17,950)
March 31, 2020	$	(499,386)	$	(141,857)	$	(792,019)	$	5,560,641
Net income	—		134,321		—		134,321
Other comprehensive loss (Note F)	(25,517)		—		—		(25,517)
Preferred stock dividends - $13.75 per share (Note E)	—		—		—		(275)
Common stock issued	—		—		10,530		949,867
Common stock dividends - $0.935 per share (Note E)	—		—		—		(387,037)
Other, net	—		—		—		8,652
June 30, 2020	$	(524,903)	$	(7,536)	$	(781,489)	$	6,240,652
Net income	—		312,316		—		312,316
Other comprehensive loss (Note F)	(5,715)		—		—		(5,715)
Preferred stock dividends - $13.75 per share (Note E)	—		(275)		—		(275)
Common stock issued	—		—		4,986		5,789
Common stock dividends - $0.935 per share (Note E)	—		(304,505)		—		(415,453)
Other, net	—		—		—		8,798
September 30, 2020	$	(530,618)	$	—	$	(776,503)	$	6,146,112

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Continued)
(Unaudited)	Common Stock Issued	Preferred Stock Issued	Common Stock		Preferred Stock		Paid-in Capital
	(Shares)		(Thousands of dollars)
January 1, 2019	445,016,234	20,000	$	4,450	$	—	$	7,615,138
Cumulative effect adjustment for adoption of ASU 2016-02, “Leases (Topic 842)”	—	—	—		—		—
Net income	—	—	—		—		—
Other comprehensive loss	—	—	—		—		—
Preferred stock dividends - $13.75 per share	—	—	—		—		—
Common stock issued	—	—	—		—		(24,779)
Common stock dividends - $0.86 per share	—	—	—		—		(17,438)
Other, net	—	—	—		—		(45,074)
March 31, 2019	445,016,234	20,000	$	4,450	$	—	$	7,527,847
Net income	—	—	—		—		—
Other comprehensive loss	—	—	—		—		—
Preferred stock dividends - $13.75 per share	—	—	—		—		—
Common stock issued	—	—	—		—		6,335
Common stock dividends - $0.865 per share	—	—	—		—		(45,728)
Other, net	—	—	—		—		7,004
June 30, 2019	445,016,234	20,000	$	4,450	$	—	$	7,495,458
Net income	—	—	—		—		—
Other comprehensive loss	—	—	—		—		—
Preferred stock dividends - $13.75 per share	—	—	—		—		—
Common stock issued	—	—	—		—		4,238
Common stock dividends - $0.89 per share	—	—	—		—		(58,960)
Other, net	—	—	—		—		7,363
September 30, 2019	445,016,234	20,000	$	4,450	$	—	$	7,448,099

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ONEOK, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Continued)
(Unaudited)	Accumulated Other Comprehensive Loss		Retained Earnings		Treasury Stock		Total Equity
	(Thousands of dollars)
January 1, 2019	$	(188,239)	$	—	$	(851,806)	$	6,579,543
Cumulative effect adjustment for adoption of ASU 2016-02, “Leases (Topic 842)”	—		(67)		—		(67)
Net income	—		337,208		—		337,208
Other comprehensive loss	(81,285)		—		—		(81,285)
Preferred stock dividends - $13.75 per share	—		(275)		—		(275)
Common stock issued	—		—		31,039		6,260
Common stock dividends - $0.86 per share	—		(336,866)		—		(354,304)
Other, net	—		—		—		(45,074)
March 31, 2019	$	(269,524)	$	—	$	(820,767)	$	6,442,006
Net income	—		311,963		—		311,963
Other comprehensive loss	(66,872)		—		—		(66,872)
Preferred stock dividends - $13.75 per share	—		(275)		—		(275)
Common stock issued	—		—		5,391		11,726
Common stock dividends - $0.865 per share	—		(311,688)		—		(357,416)
Other, net	—		—		—		7,004
June 30, 2019	$	(336,396)	$	—	$	(815,376)	$	6,348,136
Net income	—		309,155		—		309,155
Other comprehensive loss	(84,708)		—		—		(84,708)
Preferred stock dividends - $13.75 per share	—		(275)		—		(275)
Common stock issued	—		—		2,837		7,075
Common stock dividends - $0.89 per share	—		(308,880)		—		(367,840)
Other, net	—		—		—		7,363
September 30, 2019	$	(421,104)	$	—	$	(812,539)	$	6,218,906

See accompanying Notes to Consolidated Financial Statements.

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ONEOK, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

A.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited Consolidated Financial Statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2019 year-end Consolidated Balance Sheet data was derived from our audited Consolidated Financial Statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior year Consolidated 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.

In March 2020, the CARES Act was signed into law in response to the COVID-19 pandemic, and we opted into the CARES Act payroll tax deferral program, which will modestly benefit us, and the 401(k) penalty-free hardship withdrawal and loan deferral programs for employees.

Goodwill Impairment Review - We assess our goodwill for impairment at least annually as of July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. At July 1, 2020, we assessed qualitative factors subsequent to our first quarter 2020 impairment charges discussed below, to determine whether it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were less than their carrying amount. After assessing qualitative factors (including macroeconomic conditions, industry and market considerations, cost factors and overall financial performance), we determined that it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were not less than their respective carrying value, no further testing was necessary and goodwill was not considered impaired. At July 1, 2020, there was no remaining goodwill associated with our Natural Gas Gathering and Processing reporting unit.

Impairment Charges - Late in the first quarter 2020, we experienced a significant decline in our share price and market capitalization as the energy industry experienced historic events that led to a simultaneous demand and supply disruption. The World Health Organization declared COVID-19 a global pandemic and recommended containment and mitigation measures worldwide, which contributed to a massive economic slowdown and decreased demand for crude oil. In addition, Saudi Arabia and Russia increased production of crude oil as the two countries competed for market share. As a result, the global supply of crude oil significantly exceeded demand and led to a collapse in crude oil prices. Based on these events, we performed a Step 1 analysis in the first quarter 2020 to test our goodwill for impairment and evaluated certain long-lived asset groups and equity investments for impairment.

Goodwill - In the Step 1 analysis, an assessment is made by comparing the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying value of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. In January 2020, we adopted ASU 2017-04 in which the requirement to calculate the implied fair value of goodwill under the two-step impairment test was eliminated.

To estimate the fair value of our reporting units, we use two generally accepted valuation approaches, an income approach and a market approach, using assumptions consistent with a market participant’s perspective. Under the income approach, we use anticipated cash flows over a period of years plus a terminal value and discount these amounts to their present value using appropriate discount rates. Under the market approach, we apply EBITDA multiples to forecasted EBITDA. The multiples used are consistent with historical asset transactions. The forecasted cash flows are based on average forecasted cash flows for a reporting unit over a period of years.

Based on the results of our impairment test, we concluded that the carrying value of the Natural Gas Gathering and Processing reporting unit exceeded its estimated fair value, resulting in a noncash impairment charge of $153.4 million, which is included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020. The estimated fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units substantially exceeded their respective carrying values.

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The following table sets forth our goodwill, by segment, for the periods indicated:

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Natural Gas Gathering and Processing	$	—	$	153,404
Natural Gas Liquids	371,217		371,217
Natural Gas Pipelines	156,375		156,375
Total goodwill	$	527,592	$	680,996

Long-lived assets - We assess our long-lived assets for impairment whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable. An impairment is indicated if the carrying amount of a long-lived asset exceeds the sum of the undiscounted future cash flows expected to result from the use and eventual disposition of the asset. If an impairment is indicated, we record an impairment loss equal to the difference between the carrying value and the fair value of the long-lived asset.

In the first quarter 2020, we evaluated our Natural Gas Gathering and Processing segment asset groups and determined that the carrying value of certain long-lived asset groups in western Oklahoma, Kansas and the Powder River Basin, where lower pricing impacted drilling and production levels, were not recoverable and exceeded their estimated fair value. We recorded noncash impairment charges of $380.5 million, which includes impairment to intangible assets of $19.9 million related to supply contracts. In our Natural Gas Liquids segment, we recorded noncash impairment charges of $70.2 million related to certain inactive assets, as our expectation for future use of the assets changed. These charges are included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020.

Investments in unconsolidated affiliates - The impairment test for equity-method investments considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary. Therefore, we periodically evaluate the amount at which we carry our equity-method investments to determine whether current events or circumstances warrant adjustments to our carrying values.

In the first quarter 2020, we evaluated our investments in unconsolidated affiliates and concluded that the carrying value of our 10.2% investment in Venice Energy Services Company in our Natural Gas Gathering and Processing segment exceeded its estimated fair value, resulting in a noncash impairment charge of $30.5 million, which includes an impairment to our equity-method goodwill of $22.3 million. We also concluded that the carrying value of our 50% investment in Chisholm Pipeline Company in our Natural Gas Liquids segment exceeded its estimated fair value, resulting in a noncash impairment charge of $7.2 million. These impairment charges are included within impairment of equity investments in our Consolidated Statement of Income for the nine months ended September 30, 2020.

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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 or in our Annual Report were assessed and determined to be either not applicable or clarifications of ASUs previously issued or listed below. Except as discussed below or in our Annual Report, there have been no new accounting pronouncements that have become effective or have been issued that are of significance or potential significance to us. The following table provides a brief description of recently adopted 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
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	The impact of adopting this standard was not material.
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 adopted and implemented this standard prior to recording noncash impairment charges related to our goodwill, as described above.
ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting”	The standard provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met.	First quarter 2020	The impact of adopting this standard was not material.

B.    FAIR VALUE MEASUREMENTS

Determining Fair Value - For our fair value measurements, we utilize market prices, third-party pricing services, present value methods and standard option valuation models to determine the price we would receive from the sale of an asset or the transfer of a liability in an orderly transaction at the measurement date. 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.

Many of the contracts in our derivative portfolio are executed in liquid markets where price transparency exists. Our financial commodity derivatives are generally settled through a NYMEX or Intercontinental Exchange (ICE) clearing broker account with daily margin requirements. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

We compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from the implied forward LIBOR yield curve. The fair value of our forward-starting interest-rate swaps is determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest-rate swap settlements. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using counterparty-specific bond yields. Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ materially from our estimates.

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

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

•Level 2 - fair value measurements are based on significant observable pricing inputs, including quoted prices for similar assets and liabilities in active markets and inputs from third-party pricing services supported with corroborative evidence. These balances are composed of over-the-counter interest-rate derivatives.

•Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including internally developed commodity price curves that incorporate market data from broker quotes and third-party pricing services. These balances are composed predominantly of exchange-cleared and over-the-counter derivatives to hedge NGL price risk and natural gas basis risk between various transaction locations and the NYMEX Henry Hub. Our commodity derivatives are generally valued using forward quotes provided by third-party pricing services that are validated with other market data. We believe any measurement uncertainty at September 30, 2020, is immaterial as our Level 3 fair value measurements are based on unadjusted pricing information from broker quotes and third-party pricing services. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as our derivatives are primarily accounted for as hedges.

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, 2020
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Total derivative assets	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Derivative liabilities
Commodity contracts
Financial contracts	$	(13,509)	$	—	$	(47,240)	$	(60,749)	$	60,749	$	—
Interest-rate contracts	—		(231,991)		—		(231,991)		—		(231,991)
Total derivative liabilities	$	(13,509)	$	(231,991)	$	(47,240)	$	(292,740)	$	60,749	$	(231,991)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2020, we held no cash and posted $48.2 million of cash with various counterparties, including $13.9 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $34.3 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheet.

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	December 31, 2019
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	10,892	$	—	$	55,557	$	66,449	$	(28,588)	$	37,861
Interest-rate contracts	—		581		—		581		—		581
Total derivative assets	$	10,892	$	581	$	55,557	$	67,030	$	(28,588)	$	38,442
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,811)	$	—	$	(24,785)	$	(29,596)	$	28,588	$	(1,008)
Interest-rate contracts	—		(201,941)		—		(201,941)		—		(201,941)
Total derivative liabilities	$	(4,811)	$	(201,941)	$	(24,785)	$	(231,537)	$	28,588	$	(202,949)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2019, we held no cash and posted $8.8 million of cash with various counterparties, which is included in other current assets in our Consolidated Balance Sheet.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Derivative Assets (Liabilities)	2020		2019		2020		2019
	(Thousands of dollars)
Net assets at beginning of period	$	5,583	$	19,274	$	30,772	$	40,484
Total changes in fair value:
Settlements included in net income (a)	(6,194)		(12,380)		(29,471)		(38,044)
New Level 3 derivatives included in other comprehensive loss (b)	(2,033)		2,728		(5,140)		17,528
Unrealized change included in other comprehensive loss (b)	(2,700)		18,593		(1,505)		8,247
Net assets (liabilities) at end of period	$	(5,344)	$	28,215	$	(5,344)	$	28,215

(a) - Included in commodity sales revenues/cost of sales and fuel in our Consolidated Statements of Income.

(b) - Included in change in fair value of derivatives in our Consolidated Statements of Comprehensive Income.

During the three and nine months ended September 30, 2020 and 2019, there were no transfers in or out of Level 3 of the fair value hierarchy.

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 composed 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 $14.9 billion and $13.8 billion at September 30, 2020, and December 31, 2019, respectively. The book value of our consolidated long-term debt, including current maturities, was $14.3 billion and $12.5 billion at September 30, 2020, and December 31, 2019, respectively. The estimated fair value of the aggregate long-term debt 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.

Nonrecurring Fair Value Measurements - In the first quarter 2020, we incurred noncash impairment charges for certain long-lived assets and equity investments. The valuation of these assets and investments required the use of significant unobservable inputs. To estimate the fair value, we used two generally accepted valuation approaches, an income approach and a market approach. Under the income approach, our discounted cash flow analysis included the following inputs that are not readily available: a discount rate reflective of industry cost of capital, our estimated contract rates, volumes, operating and maintenance costs and capital expenditures. Under the market approach, our inputs included EBITDA multiples, which were estimated from recent peer acquisition transactions, and forecasted EBITDA, which incorporates inputs similar to those used under the income

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approach. The estimated fair value of these assets is classified as Level 3. See Note A for additional information about our impairment charges.

C.    RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - We are sensitive to changes in natural gas, crude oil and NGL prices, principally as a result of contractual terms under which these commodities are processed, purchased and sold. We are also subject to the risk of interest-rate fluctuation in the normal course of business. 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 our risk-management activities. We have not used these instruments for trading purposes.

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 may use the following commodity derivative instruments to reduce 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.

In our Natural Gas Gathering and Processing segment, we are exposed to commodity price risk as a result of retaining a portion of the commodity sales proceeds associated with our POP with fee contracts. Under certain POP with fee contracts, our fees and POP percentage may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. In certain commodity price environments, our contractual fees on these certain POP with fee contracts may decrease, which impacts the average fee rate in our Natural Gas Gathering and Processing segment. We also are exposed to basis risk between the various production and market locations where we buy and sell 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.

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

In our Natural Gas Pipelines segment, we are primarily exposed to commodity price risk on our intrastate pipelines because they consume natural gas in operations and retain natural gas from our customers for operations or as part of our fee for services provided. When the amount consumed in operations differs from the amount provided by our customers, our pipelines must buy or sell natural gas, or store or use natural gas inventory, which can expose this segment to commodity price risk depending on the regulatory treatment for this activity. To the extent that commodity price risk in our 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 natural gas price fluctuations. At September 30, 2020, and December 31, 2019, there were no financial derivative instruments with respect to our 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. In March 2020, we settled $750 million of our forward-starting interest-rate swaps related to our underwritten public offerings of

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$1.75 billion senior unsecured notes resulting in a loss of $152.5 million, which is included in accumulated other comprehensive loss and will be amortized to interest expense over the term of the related debt. In May 2020, we settled the remaining $1.3 billion of our interest-rate swaps used to hedge our LIBOR-based interest payments resulting in a loss of $48.3 million, which was recognized into interest expense upon repayment of our $1.5 Billion Term Loan Agreement.

At September 30, 2020, and December 31, 2019, we had forward-starting interest-rate swaps with notional amounts totaling $1.1 billion and $1.8 billion, respectively, to hedge the variability of interest payments on a portion of our forecasted debt issuances. At December 31, 2019, we had interest-rate swaps with notional amounts totaling $1.3 billion to hedge the variability of our LIBOR-based interest payments, all of which have settled as of September 30, 2020. All of our 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 B for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of our derivative instruments presented on a gross basis for the periods indicated:

		September 30, 2020				December 31, 2019
	Location in our Consolidated Balance Sheets	Assets		(Liabilities)		Assets		(Liabilities)
Derivatives designated as hedging instruments		(Thousands of dollars)
Commodity contracts (a)
Financial contracts (b)	Other current assets	$	46,451	$	(60,373)	$	64,858	$	(26,997)
	Other deferred credits	—		—		1,591		(2,599)
Interest-rate contracts	Other current liabilities	—		—		—		(90,161)
	Other assets/other deferred credits	—		(231,991)		581		(111,780)
Total derivatives designated as hedging instruments		46,451		(292,364)		67,030		(231,537)
Derivatives not designated as hedging instruments
Commodity contracts (a)
Financial contracts (b)		408		(376)		—		—
Total derivatives not designated as hedging instruments		408		(376)		—		—
Total derivatives		$	46,859	$	(292,740)	$	67,030	$	(231,537)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us.

(b) - At September 30, 2020, our derivative net liability positions under master-netting arrangements for financial contracts were fully offset by $13.9 million of cash collateral.

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

		September 30, 2020				December 31, 2019
	Contract Type	Purchased/ Payor		Sold/ Receiver		Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
- Crude oil and NGLs (MMBbl)	Futures	15.3		(22.7)		7.9		(17.4)
Basis
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
Interest-rate contracts (Billions of dollars)	Swaps	$	1.1	$	—	$	3.1	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—
- Crude oil and NGLs (MMBbl)	Futures	0.2		(0.2)		—		—
Basis
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—

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

Cash Flow Hedges - The following table sets forth the unrealized change in fair value of cash flow hedges in other comprehensive loss for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Commodity contracts	$	(29,667)	$	32,169	$	18,472	$	43,877
Interest-rate contracts	9,213		(128,041)		(237,200)		(303,351)
Total unrealized change in fair value of cash flow hedges in other comprehensive loss	$	(20,454)	$	(95,872)	$	(218,728)	$	(259,474)

The following table sets forth the effect of cash flow hedges on net income for the periods indicated:

	Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income	Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2020		2019		2020		2019
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	2,167	$	38,234	$	100,304	$	85,375
	Cost of sales and fuel	(1,568)		(19,706)		(31,057)		(32,751)
Interest-rate contracts (a)	Interest expense	(8,998)		(6,903)		(83,817)		(14,222)
Total change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income on derivatives		$	(8,399)	$	11,625	$	(14,570)	$	38,402

(a) - The nine months ended September 30, 2020, includes a loss of $48.3 million on the settlement of our remaining $1.3 billion interest-rate swaps used to hedge our LIBOR-based interest payments.

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 use internally developed credit ratings for counterparties that do not have a credit rating.

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Our financial commodity derivatives are generally settled through a NYMEX or Intercontinental Exchange (ICE) clearing broker account with daily margin requirements. However, we may enter into financial derivative instruments that contain provisions that require us to maintain an investment-grade credit rating from S&P and/or Moody’s. If our credit ratings on our 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, 2020.

The counterparties to our derivative contracts typically consist 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, 2020, the credit exposure from our derivative assets is with investment-grade companies in the financial services sector.

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D.    DEBT

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

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Commercial paper outstanding, bearing a weighted-average interest rate of 2.16% as of December 31, 2019	$	—	$	220,000
Senior unsecured obligations:
$1,500,000 term loan at 2.7% as of December 31, 2019, due November 2021	—		1,250,000
$700,000 at 4.25% due February 2022	547,397		547,397
$900,000 at 3.375% due October 2022	900,000		900,000
$425,000 at 5.0% due September 2023	425,000		425,000
$500,000 at 7.5% due September 2023	500,000		500,000
$500,000 at 2.75% due September 2024	500,000		500,000
$500,000 at 4.9% due March 2025	500,000		500,000
$400,000 at 2.2% due September 2025	387,000		—
$600,000 at 5.85% due January 2026	600,000		—
$500,000 at 4.0% due July 2027	500,000		500,000
$800,000 at 4.55% due July 2028	800,000		800,000
$100,000 at 6.875% due September 2028	100,000		100,000
$700,000 at 4.35% due March 2029	700,000		700,000
$750,000 at 3.4% due September 2029	714,251		750,000
$850,000 at 3.1% due March 2030	780,093		—
$600,000 at 6.35% due January 2031	600,000		—
$400,000 at 6.0% due June 2035	400,000		400,000
$600,000 at 6.65% due October 2036	600,000		600,000
$600,000 at 6.85% due October 2037	600,000		600,000
$650,000 at 6.125% due February 2041	650,000		650,000
$400,000 at 6.2% due September 2043	400,000		400,000
$700,000 at 4.95% due July 2047	689,006		700,000
$1,000,000 at 5.2% due July 2048	1,000,000		1,000,000
$750,000 at 4.45% due September 2049	723,736		750,000
$500,000 at 4.5% due March 2050	453,585		—
$300,000 at 7.15% due January 2051	300,000		—
Guardian Pipeline
Weighted average 7.85% due December 2022	15,570		21,307
Total debt	14,385,638		12,813,704
Unamortized portion of terminated swaps	13,743		15,032
Unamortized debt issuance costs and discounts	(142,392)		(121,329)
Current maturities of long-term debt	(7,650)		(7,650)
Short-term borrowings (a)	—		(220,000)
Long-term debt	$	14,249,339	$	12,479,757

(a) - Individual issuances of commercial paper under our commercial paper program generally mature in 90 days or less.

$2.5 Billion Credit Agreement - Our $2.5 Billion Credit Agreement is a revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of net indebtedness to adjusted EBITDA (EBITDA, as defined in our $2.5 Billion 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 at September 30, 2020. In June 2020, we amended the $2.5 Billion Credit Agreement by, among other things, modifying the leverage ratio so that we may net up to $700 million of cash on hand against our consolidated indebtedness for purposes of calculating the ratio’s numerator for the fiscal quarters ending June 30, 2020, September 30, 2020, and December 31, 2020. At September 30, 2020, we had no outstanding borrowings, our ratio of net indebtedness to adjusted EBITDA was 4.6 to 1, and we were in compliance with all covenants under our $2.5 Billion Credit Agreement.

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In October 2020, we acquired additional interests in one of our equity investments and a related asset for $27 million, which allowed us to elect an acquisition adjustment period under our $2.5 Billion Credit Agreement and, as a result, increased our leverage ratio covenant to 5.5 to 1 for the fourth quarter 2020 and the two following quarters.

Debt Issuances - In May 2020, we completed an underwritten public offering of $1.5 billion senior unsecured notes consisting of $600 million, 5.85% senior notes due 2026; $600 million, 6.35% senior notes due 2031; and $300 million, 7.15% senior notes due 2051. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.48 billion. A portion of the proceeds were used to repay the outstanding borrowings under our $1.5 Billion Term Loan Agreement. The remainder was used for general corporate purposes.

In March 2020, we completed an underwritten public offering of $1.75 billion senior unsecured notes consisting of $400 million, 2.2% senior notes due 2025; $850 million, 3.1% senior notes due 2030; and $500 million, 4.5% senior notes due 2050. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.73 billion. A portion of the proceeds were used to pay all outstanding amounts under our commercial paper program. The remainder was used for general corporate purposes, which included repayment of other existing indebtedness and funding capital expenditures.

Debt Repayments - In May 2020, we repaid the remaining $1.25 billion of our $1.5 Billion Term Loan Agreement with cash on hand from our May 2020 public offering of $1.5 billion senior unsecured notes.

During the three and nine months ended September 30, 2020, we repurchased in the open market outstanding principal of certain of our senior notes in the amounts of $28.0 million and $202.3 million, respectively, for an aggregate repurchase price of $25.4 million and $177.7 million, respectively, with cash on hand. In connection with these open market repurchases, we recognized $2.2 million and $22.2 million of gains on extinguishment of debt, which is included in other income in our Consolidated Statement of Income for the three and nine months ended September 30, 2020, respectively.

Debt Guarantees - We, ONEOK Partners and the Intermediate Partnership have cross guarantees in place for our and ONEOK Partners’ indebtedness.

For additional discussion of our $2.5 Billion Credit Agreement, see Note F of the Notes to Consolidated Financial Statements in our Annual Report.

E.    EQUITY

Equity Issuances - In July 2020, we established an “at-the-market” equity program for the offer and sale from time to time of our common stock up to an aggregate offering price of $1.0 billion. The program allows us to offer and sell common stock at prices we deem appropriate through a sales agent, in forward sales transactions through a forward seller or directly to one or more of the program’s managers acting as principals. Sales of our common stock may be made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. No shares have been sold through our “at-the-market” program as of the date of this report.

In June 2020, we completed an underwritten public offering of 29.9 million shares of our common stock at a public offering price of $32.00 per share, generating net proceeds, after deducting underwriting discounts, commissions and offering expenses, of $937.0 million. A portion of the proceeds were, and we anticipate the remainder will be, used for general corporate purposes, including repayment of existing indebtedness and funding capital expenditures.

Dividends - Holders of our common stock share equally in any dividend declared by our Board of Directors, subject to the rights of the holders of outstanding preferred stock. Dividends paid on our common stock in February 2020, May 2020 and August 2020 were $0.935 per share. A dividend of $0.935 per share was declared for shareholders of record at the close of business on November 2, 2020, payable November 13, 2020.

Our Series E Preferred Stock pays 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% per year. We paid dividends for the Series E Preferred Stock of $0.3 million in February 2020, May 2020 and August 2020. Dividends totaling $0.3 million were declared for the Series E Preferred Stock and are payable November 13, 2020.

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F.    ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Risk- Management Assets/Liabilities (a)		Retirement and Other Postretirement Benefit Plan Obligations (a) (b)		Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)		Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2020	$	(233,520)	$	(131,481)	$	(8,999)	$	(374,000)
Other comprehensive income (loss) before reclassifications	(168,421)		59		(10,893)		(179,255)
Amounts reclassified to net income (c)	11,210		10,626		801		22,637
Other comprehensive income (loss)	(157,211)		10,685		(10,092)		(156,618)
September 30, 2020	$	(390,731)	$	(120,796)	$	(19,091)	$	(530,618)

(a) - All amounts are presented net of tax.

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

(c) - See Note C for details of amounts reclassified to net income for risk-management assets/liabilities and Note H for retirement and other postretirement benefit plan obligations.

The following table sets forth information about the balance of accumulated other comprehensive loss at September 30, 2020, representing unrealized gains (losses) related to risk-management assets and liabilities:

	Risk- Management Assets/Liabilities (a)
	(Thousands of dollars)
Commodity derivative instruments expected to be realized within the next 15 months (b)	$	(10,988)
Settled interest-rate swaps to be recognized over the life of the long-term, fixed-rate debt (c)	(201,110)
Interest-rate swaps with future settlement dates expected to be amortized over the life of long-term debt	(178,633)
Accumulated other comprehensive loss at September 30, 2020	$	(390,731)

(a) - All amounts are presented net of tax.

(b) - Based on September 30, 2020, commodity prices, we expect $8.4 million in net losses, net of tax, over the next 12 months and $2.6 million in net losses, net of tax, thereafter.

(c) - We expect net losses of $30.3 million, net of tax, will be reclassified into earnings during the next 12 months.

The remaining amounts in accumulated other comprehensive loss relate primarily to our retirement and other postretirement benefit plan obligations, which are expected to be amortized over the average remaining service period of employees participating in these plans.

G.    EARNINGS PER SHARE

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

	Three Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	312,041	445,103	$	0.70
Diluted EPS
Effect of dilutive securities	—		407
Net income available for common stock and common stock equivalents	$	312,041	445,510	$	0.70

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	Three Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	308,880	413,816	$	0.75
Diluted EPS
Effect of dilutive securities	—		1,762
Net income available for common stock and common stock equivalents	$	308,880	415,578	$	0.74

	Nine Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	303,955	426,369	$	0.71
Diluted EPS
Effect of dilutive securities	—		628
Net income available for common stock and common stock equivalents	$	303,955	426,997	$	0.71

	Nine Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	957,501	413,443	$	2.32
Diluted EPS
Effect of dilutive securities	—		1,834
Net income available for common stock and common stock equivalents	$	957,501	415,277	$	2.31

H.    EMPLOYEE BENEFIT PLANS

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

	Retirement Benefits				Other Postretirement Benefits
	Three Months Ended				Three Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	2,036	$	1,954	$	115	$	117
Interest cost	4,574		5,126		442		509
Expected return on plan assets	(6,232)		(5,892)		(722)		(570)
Amortization of prior service cost (credit) (a)	28		—		—		(57)
Amortization of net loss (a)	4,571		3,158		1		74
Net periodic benefit cost (income)	$	4,977	$	4,346	$	(164)	$	73

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $1.1 million and $0.7 million reclassified to income tax expense for the three months ended September 30, 2020 and 2019, respectively.

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	Retirement Benefits				Other Postretirement Benefits
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	6,108	$	5,862	$	345	$	351
Interest cost	13,722		15,378		1,326		1,527
Expected return on plan assets	(18,696)		(17,676)		(2,166)		(1,710)
Amortization of prior service cost (credit) (a)	84		—		—		(171)
Amortization of net loss (a)	13,713		9,474		3		222
Net periodic benefit cost (income)	$	14,931	$	13,038	$	(492)	$	219

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $3.2 million and $2.2 million reclassified to income tax expense for the nine months ended September 30, 2020 and 2019, respectively.

I.    UNCONSOLIDATED AFFILIATES

Equity in Net Earnings from Investments and Impairments - The following table sets forth our equity in net earnings (loss) from investments for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Northern Border Pipeline	$	22,037	$	16,102	$	57,028	$	50,593
Overland Pass Pipeline	8,007		15,481		30,090		48,340
Roadrunner	8,033		7,421		21,275		19,836
Other	(31)		(1,428)		(392)		(3,594)
Equity in net earnings from investments	$	38,046	$	37,576	$	108,001	$	115,175
Impairment of equity investments	$	—	$	—	$	(37,730)	$	—

In the first quarter 2020, we incurred a noncash impairment charge of $30.5 million related to our 10.2% investment in Venice Energy Services Company in our Natural Gas Gathering and Processing segment, which includes $22.3 million related to equity-method goodwill, and a $7.2 million noncash impairment charge related to our 50% investment in Chisholm Pipeline Company in our Natural Gas Liquids segment. Our remaining equity-method goodwill was $16.5 million at September 30, 2020. For additional information on our impairment charges, see Note A.

We incurred expenses in transactions with unconsolidated affiliates of $35.8 million and $41.9 million for the three months ended September 30, 2020 and 2019, respectively, and $108.4 million and $124.2 million for the nine months ended September 30, 2020 and 2019, respectively, primarily related to Overland Pass Pipeline and Northern Border Pipeline. Accounts payable to our equity-method investees at September 30, 2020, and December 31, 2019, were $13.3 million and $13.5 million, respectively.

We have an operating agreement with Roadrunner that provides for reimbursement or payment to us for management services and certain operating costs. Reimbursements and payments from Roadrunner included in operating income in our Consolidated Statements of Income for the three and nine months ended September 30, 2020 and 2019, were not material.

J.    COMMITMENTS AND CONTINGENCIES

Environmental Matters and Pipeline Safety - The operation of pipelines, plants and other facilities for the gathering, processing, fractionation, 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, we must comply with laws and regulations that relate to air and water quality, hazardous and solid waste management and disposal, cultural resource protection and other environmental and safety matters. The cost of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with these laws, regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially

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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 or construction.

Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of these 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.

K.    LEASES

In December 2019, we entered into an operating lease for pipeline capacity with a lease term of 10 years that commenced January 1, 2020. In connection with this lease, we recognized an operating lease right-of-use asset and a lease liability with remaining balances of $70.7 million and $71.4 million, respectively, as of September 30, 2020. During the nine months ended September 30, 2020, we entered into certain operating leases and recognized operating lease right-of-use assets and lease liabilities with remaining balances of $16.2 million at the end of the period. At September 30, 2020, the weighted-average remaining lease term and the weighted-average discount rate for our operating leases were 8.5 years and 3.19%, respectively.

The following table sets forth supplemental cash flow information related to our leases:

	Nine Months Ended
	September 30,
	2020		2019
	(Thousands of dollars)
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	9,662	$	4,972
Financing cash flows for finance lease	$	1,443	$	1,307
Right-of-use assets obtained in exchange for operating lease liabilities (noncash)	$	99,197	$	3,663

The following table sets forth the maturity of our lease liabilities as of September 30, 2020:

	Finance Lease		Operating Leases
	(Millions of dollars)
Remainder of 2020	$	1.2	$	4.1
2021	4.5		16.4
2022	4.5		15.1
2023	4.5		13.8
2024	4.5		12.5
2025 and beyond	17.1		58.2
Total lease payments	36.3		120.1
Less: Interest	11.5		15.6
Present value of lease liabilities	$	24.8	$	104.5

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L.    REVENUES

Accounting Policies - Our revenue recognition policy is described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

Contract Assets and Contract Liabilities - Our contract asset balances at the beginning and end of the period primarily relate to our firm service transportation contracts with tiered rates, which are not material. The following table sets forth the balances in contract liabilities for the periods indicated:

Contract Liabilities	(Millions of dollars)
Balance at December 31, 2019 (a)	$	57.1
Revenue recognized included in beginning balance (b)	(35.1)
Net additions	24.3
Balance at September 30, 2020 (c)	$	46.3

(a) - Contract liabilities of $22.2 million and $34.9 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

(b) - Includes a contract settlement in the second quarter 2020 of revenue previously deferred.

(c) - Contract liabilities of $27.6 million and $18.7 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

Receivables from Customers and Revenue Disaggregation - Substantially all of the balances in accounts receivable on our Consolidated Balance Sheets at September 30, 2020, and December 31, 2019, relate to customer receivables. Revenues sources are disaggregated in Note M.

Transaction Price Allocated to Unsatisfied Performance Obligations - We do not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) variable consideration on contracts for which we recognize revenue at the amount to which we have the right to invoice for services performed.

The following table presents aggregate value allocated to unsatisfied performance obligations as of September 30, 2020, and the amounts we expect to recognize in revenue in future periods, related primarily to firm transportation and storage contracts with remaining contract terms ranging from one month to 24 years:

Expected Period of Recognition in Revenue	(Millions of dollars)
Remainder of 2020	$	87.1
2021	320.0
2022	259.9
2023	230.9
2024 and beyond	901.0
Total estimated transaction price allocated to unsatisfied performance obligations	$	1,798.9

The table above excludes variable consideration allocated entirely to wholly unsatisfied performance obligations, wholly unsatisfied promises to transfer distinct goods or services that are part of a single performance obligation and consideration we determine to be fully constrained. The amounts we determined to be fully constrained relate to future sales obligations under long-term sales contracts where the transaction price is not known and minimum volume agreements, which we consider to be fully constrained until invoiced.

M.    SEGMENTS

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

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

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

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

Other and eliminations consist of corporate costs, the operating and leasing activities of our headquarters building and related parking facility and eliminations necessary to reconcile our reportable segments to our Consolidated Financial Statements.

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Accounting Policies - The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

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, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	239,810	$	1,658,123	$	—	$	1,897,933
Residue natural gas sales	178,492		—		3,998		182,490
Gathering, processing and exchange services revenue	36,459		132,210		—		168,669
Transportation and storage revenue	—		39,774		113,047		152,821
Other	4,644		2,110		251		7,005
Total revenues (c)	459,405		1,832,217		117,296		2,408,918
Cost of sales and fuel (exclusive of depreciation and operating costs)	(207,519)		(1,289,667)		(3,389)		(1,500,575)
Operating costs	(69,351)		(101,223)		(34,567)		(205,141)
Equity in net earnings (loss) from investments	(42)		8,018		30,070		38,046
Noncash compensation expense and other	655		1,898		427		2,980
Segment adjusted EBITDA	$	183,148	$	451,243	$	109,837	$	744,228
Depreciation and amortization	$	(66,459)	$	(71,534)	$	(14,243)	$	(152,236)
Capital expenditures	$	63,030	$	298,891	$	12,978	$	374,899

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $541.7 million, of which $495.4 million related to revenues within the segment, and cost of sales and fuel of $137.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $71.8 million and cost of sales and fuel of $9.6 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $235.6 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,897,933	$	(224,731)	$	1,673,202
Residue natural gas sales	182,490		(5,897)		176,593
Gathering, processing and exchange services revenue	168,669		—		168,669
Transportation and storage revenue	152,821		(3,597)		149,224
Other	7,005		(429)		6,576
Total revenues (a)	$	2,408,918	$	(234,654)	$	2,174,264
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,500,575)	$	234,901	$	(1,265,674)
Operating costs	$	(205,141)	$	212	$	(204,929)
Depreciation and amortization	$	(152,236)	$	(1,009)	$	(153,245)
Equity in net earnings from investments	$	38,046	$	—	$	38,046
Capital expenditures	$	374,899	$	5,143	$	380,042

(a) - Noncustomer revenue for the three months ended September 30, 2020, totaled $4.0 million related primarily to gains from derivatives on commodity contracts.

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Three Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	244,932	$	1,746,630	$	—	$	1,991,562
Residue natural gas sales	185,303		—		231		185,534
Gathering, processing and exchange services revenue	42,795		105,179		—		147,974
Transportation and storage revenue	—		46,407		119,924		166,331
Other	3,182		2,291		1,393		6,866
Total revenues (c)	476,212		1,900,507		121,548		2,498,267
Cost of sales and fuel (exclusive of depreciation and operating costs)	(210,739)		(1,438,206)		(381)		(1,649,326)
Operating costs	(91,227)		(114,903)		(40,170)		(246,300)
Equity in net earnings (loss) from investments	(1,837)		15,890		23,523		37,576
Noncash compensation expense and other	2,883		4,174		(701)		6,356
Segment adjusted EBITDA	$	175,292	$	367,462	$	103,819	$	646,573
Depreciation and amortization	$	(55,781)	$	(50,419)	$	(14,330)	$	(120,530)
Capital expenditures	$	245,745	$	738,038	$	27,767	$	1,011,550

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $379.7 million, of which $315.7 million related to revenues within the segment, and cost of sales and fuel of $129.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $72.3 million and cost of sales and fuel of $5.1 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $244.2 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,991,562	$	(230,080)	$	1,761,482
Residue natural gas sales	185,534		(567)		184,967
Gathering, processing and exchange services revenue	147,974		—		147,974
Transportation and storage revenue	166,331		(4,010)		162,321
Other	6,866		(382)		6,484
Total revenues (a)	$	2,498,267	$	(235,039)	$	2,263,228
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,649,326)	$	234,798	$	(1,414,528)
Operating costs	$	(246,300)	$	1,165	$	(245,135)
Depreciation and amortization	$	(120,530)	$	(900)	$	(121,430)
Equity in net earnings from investments	$	37,576	$	—	$	37,576
Capital expenditures	$	1,011,550	$	7,624	$	1,019,174

(a) - Noncustomer revenue for the three months ended September 30, 2019, totaled $89.0 million related primarily to gains from derivatives on commodity contracts.

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Nine Months Ended September 30, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	569,308	$	4,429,414	$	—	$	4,998,722
Residue natural gas sales	518,435		—		6,033		524,468
Gathering, processing and exchange services revenue	110,345		370,920		—		481,265
Transportation and storage revenue	—		131,410		353,188		484,598
Other	11,106		6,779		916		18,801
Total revenues (c)	1,209,194		4,938,523		360,137		6,507,854
Cost of sales and fuel (exclusive of depreciation and operating costs)	(541,910)		(3,473,575)		(5,096)		(4,020,581)
Operating costs	(232,489)		(297,771)		(100,966)		(631,226)
Equity in net earnings (loss) from investments	(1,385)		31,083		78,303		108,001
Noncash compensation expense and other	(1,865)		1,541		(184)		(508)
Segment adjusted EBITDA	$	431,545	$	1,199,801	$	332,194	$	1,963,540
Depreciation and amortization	$	(180,634)	$	(198,440)	$	(43,937)	$	(423,011)
Impairment charges	$	(564,353)	$	(77,401)	$	—	$	(641,754)
Investments in unconsolidated affiliates	$	2,276	$	426,621	$	361,476	$	790,373
Total assets	$	6,437,301	$	13,449,529	$	2,082,846	$	21,969,676
Capital expenditures	$	362,811	$	1,504,881	$	40,478	$	1,908,170

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1,454.0 million, of which $1,306.2 million related to revenues within the segment, and cost of sales and fuel of $375.0 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $225.6 million and cost of sales and fuel of $22.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $557.1 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	4,998,722	$	(513,170)	$	4,485,552
Residue natural gas sales	524,468		(10,860)		513,608
Gathering, processing and exchange services revenue	481,265		—		481,265
Transportation and storage revenue	484,598		(11,033)		473,565
Other	18,801		(1,126)		17,675
Total revenues (a)	$	6,507,854	$	(536,189)	$	5,971,665
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(4,020,581)	$	537,521	$	(3,483,060)
Operating costs	$	(631,226)	$	(5,207)	$	(636,433)
Depreciation and amortization	$	(423,011)	$	(3,003)	$	(426,014)
Impairment charges	$	(641,754)	$	—	$	(641,754)
Equity in net earnings from investments	$	108,001	$	—	$	108,001
Investments in unconsolidated affiliates	$	790,373	$	—	$	790,373
Total assets	$	21,969,676	$	811,200	$	22,780,876
Capital expenditures	$	1,908,170	$	15,833	$	1,924,003

(a) - Noncustomer revenue for the nine months ended September 30, 2020, totaled $103.0 million related primarily to gains from derivatives on commodity contracts.

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Nine Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	890,021	$	5,826,297	$	—	$	6,716,318
Residue natural gas sales	725,672		—		1,242		726,914
Gathering, processing and exchange services revenue	126,073		309,571		—		435,644
Transportation and storage revenue	—		141,384		350,029		491,413
Other	11,287		7,313		4,208		22,808
Total revenues (c)	1,753,053		6,284,565		355,479		8,393,097
Cost of sales and fuel (exclusive of depreciation and operating costs)	(971,397)		(4,914,452)		(3,785)		(5,889,634)
Operating costs	(271,236)		(340,274)		(113,043)		(724,553)
Equity in net earnings (loss) from investments	(4,660)		49,406		70,429		115,175
Noncash compensation expense and other	8,399		12,618		1,931		22,948
Segment adjusted EBITDA	$	514,159	$	1,091,863	$	311,011	$	1,917,033
Depreciation and amortization	$	(162,014)	$	(143,166)	$	(42,653)	$	(347,833)
Investments in unconsolidated affiliates	$	35,252	$	445,755	$	389,504	$	870,511
Total assets	$	6,546,417	$	11,662,489	$	2,083,773	$	20,292,679
Capital expenditures	$	674,115	$	1,969,138	$	77,861	$	2,721,114

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1.0 billion, of which $853.0 million related to revenues within the segment, and cost of sales and fuel of $364.9 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $214.7 million and cost of sales and fuel of $14.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $897.9 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	6,716,318	$	(878,958)	$	5,837,360
Residue natural gas sales	726,914		(567)		726,347
Gathering, processing and exchange services revenue	435,644		—		435,644
Transportation and storage revenue	491,413		(11,827)		479,586
Other	22,808		(984)		21,824
Total revenues (a)	$	8,393,097	$	(892,336)	$	7,500,761
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(5,889,634)	$	892,935	$	(4,996,699)
Operating costs	$	(724,553)	$	964	$	(723,589)
Depreciation and amortization	$	(347,833)	$	(2,719)	$	(350,552)
Equity in net earnings from investments	$	115,175	$	—	$	115,175
Investments in unconsolidated affiliates	$	870,511	$	—	$	870,511
Total assets	$	20,292,679	$	1,043,228	$	21,335,907
Capital expenditures	$	2,721,114	$	18,224	$	2,739,338

(a) - Noncustomer revenue for the nine months ended September 30, 2019, totaled $129.9 million related primarily to gains from derivatives on commodity contracts.

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	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Reconciliation of net income to total segment adjusted EBITDA
Net income	$	312,316	$	309,155	$	304,780	$	958,326
Add:
Interest expense, net of capitalized interest	176,371		129,577		535,955		362,490
Depreciation and amortization	153,245		121,430		426,014		350,552
Income tax expense	106,555		97,365		94,300		274,234
Impairment charges	—		—		641,754		—
Noncash compensation expense	1,606		9,757		1,261		20,412
Other corporate costs and equity AFUDC (a)	(5,865)		(20,711)		(40,524)		(48,981)
Total segment adjusted EBITDA	$	744,228	$	646,573	$	1,963,540	$	1,917,033

(a) - The three and nine months ended September 30, 2020, include corporate gains of $2.2 million and $22.2 million, respectively, on extinguishment of debt related to open market repurchases.

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.

Market Conditions - Late in the first quarter 2020, the energy industry experienced historic events that led to a simultaneous demand and supply disruption. The World Health Organization declared COVID-19 a global pandemic and recommended containment and mitigation measures worldwide, which contributed to a massive economic slowdown and decreased demand for crude oil. In addition, Saudi Arabia and Russia increased production of crude oil as the two countries competed for market share. As a result, the global supply of crude oil significantly exceeded demand and led to a collapse in crude oil prices resulting in crude oil and associated natural gas and NGLs production being curtailed. We are still experiencing global and regional economic disruption due primarily to COVID-19; however, in the third quarter 2020, many of our producers reversed curtailments, bringing production back to pre-COVID-19 levels as prices improved from second quarter 2020 lows and remained stable. Third quarter 2020 production volumes increased, compared with lows experienced during the second quarter 2020, across our system. Although the extent of volume growth in the future depends upon commodity prices and the pace and scale of economic recovery and corresponding demand for crude oil, we expect the improved volumes experienced in the third quarter 2020 to continue for the remainder of 2020 and into 2021.

We continue to monitor producers’ drilling, completion and production plans and are evaluating the impact on our future volume expectations. The energy industry has historically experienced down cycles from disruptive events, and as a result, we have positioned ourselves to minimize exposure to direct commodity price volatility. Each of our three segments’ earnings are primarily fee-based, and we expect our consolidated earnings to be more than 90% fee-based in 2020. While our Natural Gas Gathering and Processing segment’s earnings are primarily fee-based, we have direct commodity price exposure related primarily to POP with fee contracts. Under certain POP with fee contracts, our contractual fees and POP percentage may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. In addition, although our Natural Gas Gathering and Processing and Natural Gas Liquids segments generate primarily fee-based earnings, those segments’ results of operations are exposed to volumetric risk as a result of production curtailments, reduced drilling and completion activity, declining well productivity, severe weather disruptions, operational outages and ethane demand. Our Natural Gas Pipelines segment is not exposed to significant volumetric risk due to nearly all of our capacity being subscribed under long-term firm contracts.

In continued response to COVID-19, we remain committed to managing the impact of the pandemic on our employees and the communities where we operate. We are taking actions to continue safe operations, protect our workforce and implement appropriate cost reduction measures. We meaningfully reduced our operating expenses in the nine months ended

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September 30, 2020, compared with the same period in 2019, primarily as a result of reduced discretionary expenses, contractor reductions and asset optimizations. We also reduced our planned 2020 capital-growth expenditures by approximately $900 million. As always, we remain focused on operating our assets safely, reliably and in an environmentally responsible manner. We continue to monitor the COVID-19 outbreak and have implemented our business continuity plans. ONEOK is a critical infrastructure business as defined by the United States Department of Homeland Security, and, therefore, our workforce has remained fully engaged in the midst of federal, state and local government issued guidelines and safety related ordinances. We continue to practice remote work procedures when possible to protect the safety of our employees and their families, and have taken extra precautions for our employees who work in the field or need to report to a ONEOK facility, such as increased facility access restrictions, social distancing and sanitation procedures. We continue to apply risk-management and cybersecurity measures designed to ensure that our systems remain functional in order to both serve our operational needs and to provide service to our customers.

In the first quarter 2020, due to the commodity price and market environment, we experienced a significant decline in our share price and market capitalization, and performed a Step 1 analysis to test our goodwill for impairment and evaluated certain long-lived asset groups and equity investments for impairment. As a result, we incurred $641.8 million in noncash impairment charges, which had an adverse impact on our financial results for the nine months ended September 30, 2020. We expect to maintain sufficient liquidity and financial stability for the remainder of 2020 due to cash on hand from our June 2020 equity issuance, cash flows from operations and access to our undrawn $2.5 Billion Credit Agreement. In the first quarter 2020, the CARES Act was signed into law in response to the COVID-19 pandemic, and we opted into the CARES Act payroll tax deferral program, which will modestly benefit us, and the 401(k) penalty-free hardship withdrawal and loan deferral programs for employees.

See Part I, Item 3, Quantitative and Qualitative Disclosures About Market Risk, in this Quarterly Report for more information on our exposure to market risk.

Natural Gas - In our Natural Gas Gathering and Processing segment, gathered and processed volumes decreased in the nine months ended September 30, 2020, compared with the same period in 2019, due primarily to production curtailments from many of our crude oil and natural gas producers, primarily in the second quarter 2020, and natural production declines in the Mid-Continent region. In the third quarter 2020, many of our producers returned production to pre-COVID-19 levels as commodity prices strengthened. As prices and volumes continue to strengthen, we have the capacity to benefit from production growth without significant capital investment due to the recent completion of our Demicks Lake I and II natural gas processing plants, which were placed in service in the fourth quarter 2019 and the first quarter 2020, respectively. These plants have increased our total processing capacity to approximately 1.5 Bcf/d in the Williston Basin and will enable us to capture natural gas previously flared from producers on our more than 3 million dedicated acres in the Williston Basin.

Production growth may be impacted by the current litigation challenging the continued operation of the Dakota Access Pipeline (DAPL), which is used to transport crude oil from the Williston Basin to markets in the Mid-Continent region and Gulf Coast. If DAPL is temporarily or permanently shut down, production growth could be limited due to increased crude oil transportation costs and capacity constraints in the region.

NGLs - In our Natural Gas Liquids segment, we are the largest NGL takeaway provider in the Rocky Mountain region where our September 2020 average volumes exceeded pre-COVID-19 levels and increased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to increased production at new and existing processing plants. We expect the improved volumes experienced in the third quarter 2020 to continue in the remainder of 2020 and into 2021, and to benefit without significant capital investment, from our integrated value chain, which was strengthened through our recently completed capital-growth projects. Our Elk Creek pipeline was completed in two phases during the second half of 2019. During the nine months ended September 30, 2020, we completed an extension of our Bakken NGL pipeline, the construction and extension of our Arbuckle II pipeline and the construction of our 125 MBbl/d MB-4 fractionator.

Growth Projects - We operate an integrated, reliable and diversified network of natural gas gathering, processing, fractionation, storage and transportation assets connecting NGL supply in the Rocky Mountain, Mid-Continent and Permian regions with key market centers. Since the beginning of 2018, we have completed capital-growth projects that include NGL pipelines, NGL fractionators, natural gas processing plants and related natural gas and NGL infrastructure. In the first quarter 2020, due to the decline in commodity prices and economic demand disruptions caused by COVID-19, we reduced our planned 2020 capital-growth expenditures by approximately $900 million. These reductions include the suspension of our announced plans to construct the Demicks Lake III natural gas processing plant, the fourth expansion of the West Texas LPG pipeline system, a reduction in the scope of the expansion of our Elk Creek pipeline and various other paused projects, as noted in the

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table below, which can be restarted quickly when new drilling activity resumes. Our announced large capital-growth projects that have recently been completed or are in various stages of construction are outlined in the table below:

Project (e)	Scope	Approximate Costs (a)	Completion
Natural Gas Gathering and Processing		(In millions)
Demicks Lake I plant and related infrastructure	200 MMcf/d processing plant and related gathering infrastructure in the core of the Williston Basin	$400	Completed October 2019
	Supported by acreage dedications with long-term primarily fee-based contracts
Demicks Lake II plant and related infrastructure	200 MMcf/d processing plant and related gathering infrastructure in the core of the Williston Basin	$410	Completed January 2020
	Supported by acreage dedications with long-term primarily fee-based contracts
Bear Creek plant expansion and related infrastructure	200 MMcf/d processing plant expansion and related gathering infrastructure in the Williston Basin	$405	Paused (b)
	Supported by acreage dedications with long-term primarily fee-based contracts
Natural Gas Liquids
Elk Creek pipeline and related infrastructure	900-mile NGL pipeline from the Williston Basin to the Mid-Continent region, with capacity of up to 240 MBbl/d, and related infrastructure	$1,400	Completed December 2019
	Anchored by long-term contracts
	Expansion capability up to 400 MBbl/d with additional pump facilities
Arbuckle II pipeline and related infrastructure	530-mile NGL pipeline from the STACK area to Mont Belvieu, Texas, and related infrastructure	$1,360	Completed March 2020
	Supported by long-term contracts
	Expansion capability up to 1 MMBbl/d
MB-4 fractionator and related infrastructure	125 MBbl/d NGL fractionator in Mont Belvieu, Texas, and related infrastructure, which includes additional NGL storage in Mont Belvieu	$575	Completed March 2020 (c)
	Fully contracted with long-term contracts
West Texas LPG pipeline expansion and Arbuckle II connection	Increasing mainline capacity by 80 MBbl/d with additional pump facilities and pipeline looping	$295	Completed June 2020 (d)
	Connecting West Texas LPG pipeline system to the Arbuckle II pipeline
	Supported by long-term dedicated production from six third-party processing plants expected to produce up to 60 MBbl/d
Bakken NGL pipeline extension	75-mile NGL pipeline in the Williston Basin connecting to a third-party processing plant	$100	Completed August 2020
	Supported by a long-term contract with a minimum volume commitment
Arbuckle II extension project and additional gathering infrastructure	Provide additional takeaway capacity in the STACK area	$240	Completed August 2020
	Allow increasing volumes on the Elk Creek pipeline access to fractionation capacity at Mont Belvieu, Texas
Arbuckle II pipeline expansion	Increasing mainline capacity with additional pump facilities	$60	Paused (b)
	Increases capacity to 500 MBbl/d
MB-5 fractionator and related infrastructure	125 MBbl/d NGL fractionator in Mont Belvieu, Texas, and related infrastructure, which includes additional NGL storage in Mont Belvieu	$750	Paused (b)
	Fully contracted with long-term contracts
West Texas LPG pipeline expansion	Increasing mainline capacity by 40 MBbl/d	$145	Paused (b)
	Supported by long-term dedicated production from third-party processing plants expected to produce up to 45 MBbl/d
Mid-Continent fractionation facility expansions	65 MBbl/d of expansions at our Mid-Continent NGL facilities	$150	Paused (b)

(a) - Excludes capitalized interest/AFUDC.

(b) - Given the current environment, we paused the majority of construction activities on these projects and do not expect to complete construction by the original target completion date.

(c) - We completed 75 MBbl/d in December 2019 and completed the remaining 50 MBbl/d in March 2020.

(d) - We completed expansions to increase mainline capacity by approximately 45 MBbl/d in the first quarter 2020 and completed the remaining portion of this project in the second quarter 2020, which was delayed due to weather.

(e) - Projects listed exclude our suspended capital-growth projects, which include the Demicks Lake III natural gas processing plant, the fourth expansion of the West Texas LPG pipeline system and the expansion of the Elk Creek pipeline.

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Ethane Production - Ethane volumes under long-term contracts delivered to our NGL system in the third quarter 2020 averaged 410 MBbl/d, compared with 350 MBbl/d in the third quarter 2019, and increased by approximately 45 MBbl/d, compared with the second quarter 2020, due primarily to improved ethane recovery economics. We expect fluctuation in ethane volumes for the remainder of 2020 and into 2021.

Debt Issuances and Repayments - In May 2020, we completed an underwritten public offering of $1.5 billion senior unsecured notes consisting of $600 million, 5.85% senior notes due 2026; $600 million, 6.35% senior notes due 2031; and $300 million, 7.15% senior notes due 2051. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.48 billion. A portion of the proceeds were used to repay the remaining $1.25 billion outstanding on our $1.5 Billion Term Loan Agreement. The remainder was used for general corporate purposes.

In March 2020, we completed an underwritten public offering of $1.75 billion senior unsecured notes consisting of $400 million, 2.2% senior notes due 2025; $850 million, 3.1% senior notes due 2030; and $500 million, 4.5% senior notes due 2050. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.73 billion. A portion of the proceeds were used to pay all outstanding amounts under our commercial paper program. The remainder was used for general corporate purposes, which included repayment of existing indebtedness and funding capital expenditures.

During the three and nine months ended September 30, 2020, we repurchased in the open market outstanding principal of certain of our senior notes in the amounts of $28.0 million and $202.3 million, respectively, for an aggregate repurchase price of $25.4 million and $177.7 million, respectively, with cash on hand. In connection with these open market repurchases, we recognized $2.2 million and $22.2 million of gains on extinguishment of debt, which is included in other income in our Consolidated Statement of Income for the three and nine months ended September 30, 2020, respectively.

Equity Issuances - In June 2020, we completed an underwritten public offering of 29.9 million shares of our common stock at a public offering price of $32.00 per share, generating net proceeds, after deducting underwriting discounts, commissions and offering expenses, of $937.0 million. A portion of the proceeds were, and we anticipate the remainder will be, used for general corporate purposes, including repayment of existing indebtedness and funding capital expenditures.

Dividends - In February 2020, May 2020 and August 2020, we paid quarterly dividends of $0.935 per share ($3.74 per share on an annualized basis), which represented increases of 9%, 8% and 5% when compared with the dividends paid in the respective quarters in the prior year. We declared a quarterly dividend of $0.935 per share ($3.74 per share on an annualized basis) in October 2020. The quarterly dividend will be paid November 13, 2020, to shareholders of record at the close of business on November 2, 2020.

Goodwill Impairment Review - We assess our goodwill for impairment at least annually as of July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. At July 1, 2020, we assessed qualitative factors subsequent to our first quarter 2020 impairment charges discussed below, to determine whether it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were less than their carrying amount. After assessing qualitative factors (including macroeconomic conditions, industry and market considerations, cost factors and overall financial performance), we determined that it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were not less than their respective carrying value, no further testing was necessary and goodwill was not considered impaired. At July 1, 2020, there was no remaining goodwill associated with our Natural Gas Gathering and Processing reporting unit.

Impairments - Due to circumstances discussed above, in the first quarter 2020, we evaluated our goodwill, certain long-lived asset groups and equity investments for impairment. Based on the results, we recorded the following impairment charges:

Natural Gas Gathering and Processing - In the first quarter 2020, we recorded $380.5 million of noncash impairment charges related primarily to certain long-lived asset groups that were not recoverable, $153.4 million of noncash impairment charges related to goodwill and $30.5 million of noncash impairment charges related to our 10.2% investment in Venice Energy Services Company.

Natural Gas Liquids - In the first quarter 2020, we recorded $70.2 million of noncash impairment charges related to certain inactive assets and $7.2 million of noncash impairment charges related to our 50% investment in Chisholm Pipeline Company.

For additional information on our impairment charges, see Note A of the Notes to Consolidated Financial Statements in this Quarterly Report.

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FINANCIAL RESULTS AND OPERATING INFORMATION

Consolidated Operations

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

	Three Months Ended				Nine Months Ended				Three Months	Nine Months
	September 30,				September 30,				2020 vs. 2019	2020 vs. 2019
Financial Results	2020		2019		2020		2019		$ Increase (Decrease)	$ Increase (Decrease)
	(Millions of dollars)
Revenues
Commodity sales	$	1,852.2	$	1,947.8	$	5,004.4	$	6,567.6	(95.6)	(1,563.2)
Services	322.1		315.4		967.3		933.2		6.7	34.1
Total revenues	2,174.3		2,263.2		5,971.7		7,500.8		(88.9)	(1,529.1)
Cost of sales and fuel (exclusive of items shown separately below)	1,265.7		1,414.5		3,483.1		4,996.7		(148.8)	(1,513.6)
Operating costs	205.0		245.1		636.5		723.6		(40.1)	(87.1)
Depreciation and amortization	153.2		121.4		426.0		350.6		31.8	75.4
Impairment charges	—		—		604.0		—		—	604.0
(Gain) loss on sale of assets	—		—		(0.6)		2.9		—	3.5
Operating income	$	550.4	$	482.2	$	822.7	$	1,427.0	68.2	(604.3)
Equity in net earnings from investments	$	38.0	$	37.6	$	108.0	$	115.2	0.4	(7.2)
Impairment of equity investments	$	—	$	—	$	(37.7)	$	—	—	37.7
Interest expense, net of capitalized interest	$	(176.4)	$	(129.6)	$	(536.0)	$	(362.5)	46.8	173.5
Net income	$	312.3	$	309.2	$	304.8	$	958.3	3.1	(653.5)
Adjusted EBITDA	$	747.0	$	649.8	$	1,981.7	$	1,919.7	97.2	62.0
Capital expenditures	$	380.0	$	1,019.2	$	1,924.0	$	2,739.3	(639.2)	(815.3)

See reconciliation of net income to adjusted EBITDA in the “Adjusted EBITDA” section.

Changes in commodity prices and sales volumes affect both revenues and cost of sales and fuel in our Consolidated Statements of Income, and, therefore, the impact is largely offset between these line items.

Operating income increased for the three months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•Natural Gas Liquids - an increase of $103.4 million in exchange services due primarily to higher volumes across our system and lower rail and pipeline transportation costs, offset partially by a $20.9 million decrease in optimization and marketing due primarily to narrower location price differentials and lower optimization volumes; and

•a decrease of $40.1 million in operating costs due primarily to reduced discretionary expenses, lower materials and supplies expenses and lower employee-related costs; offset partially by

•an increase of $31.8 million in depreciation expense due to capital projects placed in service;

•Natural Gas Gathering and Processing - a decrease of $18.8 million due primarily to lower volumes in the Mid-Continent region due to natural production declines and in the Williston Basin as a result of production curtailments; and

•Natural Gas Pipelines - a decrease of $5.4 million in transportation services due primarily to lower interruptible revenue.

Operating income decreased for the nine months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•a decrease of $604.0 million due to noncash impairment charges in our Natural Gas Gathering and Processing and Natural Gas Liquids segments;

•Natural Gas Gathering and Processing - a decrease of $57.6 million due primarily to lower volumes in the Williston Basin as a result of production curtailments and in the Mid-Continent region due to natural production declines and a decrease of $56.8 million due primarily to lower realized prices; and

•an increase of $75.4 million in depreciation expense due to capital projects placed in service; offset partially by

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•Natural Gas Liquids - an increase of $208.8 million in exchange services due primarily to higher volumes in the Rocky Mountain region and Permian Basin, lower rail and pipeline transportation costs, lower unfractionated NGLs held in inventory and higher average fee rates primarily in the Permian Basin, offset partially by a decrease of $113.9 million in optimization and marketing due primarily to narrower location price differentials, lower optimization volumes and lower marketing earnings;

•a decrease of $87.1 million in operating costs due primarily to reduced discretionary expenses, lower materials and supplies expenses, lower employee-related costs and the noncash mark-to-market impact of our share-based deferred compensation plan; and

•Natural Gas Pipelines - an increase of $6.4 million in transportation services due primarily to higher firm transportation revenue and a $13.5 million contract settlement, offset partially by lower interruptible revenue.

Net income increased for the three months ended September 30, 2020, and decreased for the nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to the items discussed above. The nine months ended September 30, 2020, was also negatively impacted by higher interest expense related to the settlement of the remaining $1.3 billion of our interest-rate swaps used to hedge our LIBOR-based interest payments and our underwritten public debt offerings in March and May 2020 and noncash impairment charges related to equity investments in our Natural Gas Gathering and Processing and Natural Gas Liquids segments, offset partially by a gain on extinguishment of debt related to open market repurchases.

Capital expenditures decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to our previously completed capital-growth projects as well as our paused and suspended capital-growth projects related to weakened commodity prices and economic disruptions caused by COVID-19.

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

Natural Gas Gathering and Processing

Overview - Our Natural Gas Gathering and Processing segment provides midstream services to producers in North Dakota, Montana, Wyoming, Kansas and Oklahoma. Raw natural gas is typically gathered at the wellhead, compressed and transported through pipelines to our processing facilities. 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 NGLs separated from the raw natural gas are sold and delivered through NGL pipelines to fractionation facilities for further processing.

Our Natural Gas Gathering and Processing segment’s earnings are primarily fee-based, but we have some direct commodity price exposure related primarily to POP with fee contracts. Under certain POP with fee contracts, our contractual fees and POP percentage may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. Due to the current commodity price environment and production curtailments from many of our producers during the second quarter 2020, our contractual fees on these certain POP with fee contracts in the Rocky Mountain region decreased, which has impacted our 2020 average fee rate. To mitigate the impact of this commodity price exposure, we have hedged a portion of our Natural Gas Gathering and Processing segment’s commodity price risk for the remainder of 2020 and 2021. This segment has substantial long-term acreage dedications in some of the most productive areas of the Williston Basin, which helps to mitigate volumetric risk.

Growth Projects - Our Natural Gas Gathering and Processing segment has invested in growth projects in NGL-rich areas in the Williston Basin. See “Growth Projects” in the “Recent Developments” section for discussion of our capital-growth projects.

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

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

	Three Months Ended				Nine Months Ended				Three Months	Nine Months
	September 30,				September 30,				2020 vs. 2019	2020 vs. 2019
Financial Results	2020		2019		2020		2019		$ Increase (Decrease)	$ Increase (Decrease)
	(Millions of dollars)
NGL sales	$	216.3	$	198.2	$	488.7	$	743.8	18.1	(255.1)
Condensate sales	23.5		46.7		80.6		146.2		(23.2)	(65.6)
Residue natural gas sales	178.5		185.3		518.4		725.7		(6.8)	(207.3)
Gathering, compression, dehydration and processing fees and other revenue	41.1		46.0		121.5		137.4		(4.9)	(15.9)
Cost of sales and fuel (exclusive of depreciation and operating costs)	(207.5)		(210.7)		(541.9)		(971.4)		(3.2)	(429.5)
Operating costs, excluding noncash compensation adjustments	(67.4)		(87.4)		(229.8)		(259.2)		(20.0)	(29.4)
Equity in net loss from investments	—		(1.8)		(1.4)		(4.7)		1.8	3.3
Other	(1.4)		(1.0)		(4.6)		(3.6)		(0.4)	(1.0)
Adjusted EBITDA	$	183.1	$	175.3	$	431.5	$	514.2	7.8	(82.7)
Impairment charges	$	—	$	—	$	564.4	$	—	—	564.4
Capital expenditures	$	63.0	$	245.7	$	362.8	$	674.1	(182.7)	(311.3)

See reconciliation of net income to adjusted EBITDA in the “Adjusted EBITDA” section.

Changes in commodity prices and sales volumes affect both revenues and cost of sales and fuel, and, therefore, the impact is largely offset between these line items.

Adjusted EBITDA increased $7.8 million for the three months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•a decrease of $20.0 million in operating costs due primarily to lower materials and supplies expenses due to reduced asset utilization, reduced discretionary expenses and lower employee-related costs; and

•an increase of $5.2 million due primarily to higher realized prices impacting our POP with fee contracts; offset partially by

•a decrease of $18.8 million due primarily to lower volumes in the Mid-Continent region due to natural production declines and in the Williston Basin as a result of production curtailments.

Adjusted EBITDA decreased $82.7 million for the nine months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•a decrease of $57.6 million due primarily to lower volumes in the Williston Basin as a result of production curtailments and in the Mid-Continent region due to natural production declines; and

•a decrease of $56.8 million due primarily to lower realized prices impacting our POP with fee contracts; offset partially by

•a decrease of $29.4 million in operating costs due primarily to lower materials and supplies expenses due to reduced asset utilization, reduced discretionary expenses and lower employee-related costs.

The nine months ended September 30, 2020, includes $380.5 million of noncash impairment charges related primarily to certain long-lived asset groups in western Oklahoma, Kansas and the Powder River Basin that were not recoverable, a $153.4 million noncash impairment charge related to goodwill and a $30.5 million noncash impairment charge related to our 10.2% investment in Venice Energy Services Company. For additional information on our impairment charges, see Note A of the Notes to Consolidated Financial Statements in this Quarterly Report.

Capital expenditures decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to capital-growth projects completed in 2019 and early 2020, as well as several paused capital-growth projects in 2020.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information (a)	2020		2019		2020		2019
Natural gas gathered (BBtu/d)	2,514		2,825		2,503		2,742
Natural gas processed (BBtu/d) (b)	2,345		2,624		2,327		2,544
NGL sales (MBbl/d)	219		233		213		223
Residue natural gas sales (BBtu/d) (b)	1,133		1,206		1,044		1,189
Average fee rate ($/MMBtu)	$	0.94	$	0.92	$	0.84	$	0.92

(a) - Includes volumes for consolidated entities only.

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

Our natural gas gathered, natural gas processed, NGL sales and residue natural gas sales volumes decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to production curtailments from some of our crude oil and natural gas producers in the Williston Basin and natural production declines in the Mid-Continent region.

Our average fee rate decreased for the nine months ended September 30, 2020, compared with the same period in 2019, due primarily to production curtailments in the second quarter 2020 on large producer contracts with higher fees and lower POP components in the Williston Basin.

Commodity Price Risk - See discussion regarding our 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 - Our 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, which includes the Williston, Powder River and DJ Basins. We provide midstream services to producers of NGLs and deliver 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. We own or have an ownership interest in FERC-regulated NGL gathering and distribution pipelines in Oklahoma, Kansas, Texas, New Mexico, Montana, North Dakota, Wyoming and Colorado, and terminal and storage facilities in Kansas, Missouri, Nebraska, Iowa and Illinois. The majority of the pipeline-connected natural gas processing plants in the Williston Basin, Oklahoma, Kansas and the Texas Panhandle are connected to our NGL gathering systems. We lease rail cars and own and operate truck- and rail-loading and -unloading facilities connected to our NGL fractionation, storage and pipeline assets. We also own FERC-regulated NGL distribution pipelines in Kansas, Missouri, Nebraska, Iowa, Illinois and Indiana that connect our Mid-Continent assets with Midwest markets, including Chicago, Illinois. A portion of our ONEOK North System transports refined petroleum products, including unleaded gasoline and diesel, from Kansas to Iowa.

Growth Projects - Our Natural Gas Liquids segment invests in projects to transport, fractionate, store and deliver to market centers NGL supply from shale and other resource development areas. Our growth strategy is focused around connecting diversified supply basins from the Rocky Mountain region through the Mid-Continent region and the Permian Basin with NGL product demand from the petrochemical and refining industries and NGL export demand in the Gulf Coast. See “Growth Projects” in the “Recent Developments” section for discussion of our capital-growth projects.

In the nine months ended September 30, 2020, we connected two third-party natural gas processing plants in the Permian Basin and two third-party natural gas processing plants in the Rocky Mountain region to our NGL system. In addition, one affiliate and two third-party natural gas processing plants in the Rocky Mountain region and one third-party natural gas processing plant in the Mid-Continent region connected to our system were expanded.

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

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

	Three Months Ended				Nine Months Ended				Three Months	Nine Months
	September 30,				September 30,				2020 vs. 2019	2020 vs. 2019
Financial Results	2020		2019		2020		2019		$ Increase (Decrease)	$ Increase (Decrease)
	(Millions of dollars)
NGL and condensate sales	$	1,658.1	$	1,746.6	$	4,429.4	$	5,826.3	(88.5)	(1,396.9)
Exchange service revenues and other	134.3		107.5		377.7		316.9		26.8	60.8
Transportation and storage revenues	39.8		46.4		131.4		141.4		(6.6)	(10.0)
Cost of sales and fuel (exclusive of depreciation and operating costs)	(1,289.7)		(1,438.2)		(3,473.6)		(4,914.5)		(148.5)	(1,440.9)
Operating costs, excluding noncash compensation adjustments	(97.0)		(109.3)		(290.6)		(322.9)		(12.3)	(32.3)
Equity in net earnings from investments	8.0		15.9		31.1		49.4		(7.9)	(18.3)
Other	(2.3)		(1.4)		(5.6)		(4.7)		(0.9)	(0.9)
Adjusted EBITDA	$	451.2	$	367.5	$	1,199.8	$	1,091.9	83.7	107.9
Impairment charges	$	—	$	—	$	77.4	$	—	—	77.4
Capital expenditures	$	298.9	$	738.0	$	1,504.9	$	1,969.1	(439.1)	(464.2)

See reconciliation of net income to adjusted EBITDA in the “Adjusted EBITDA” section.

Changes in commodity prices and sales volumes affect both revenues and cost of sales and fuel, and, therefore, the impact is largely offset between these line items.

Adjusted EBITDA increased $83.7 million for the three months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•an increase of $103.4 million in exchange services due primarily to $48.7 million in higher volumes across our system, $43.5 million in lower costs due primarily to lower rail and pipeline transportation costs and $17.9 million related to lower unfractionated NGLs held in inventory; and

•a decrease of $12.3 million in operating costs due primarily to reduced discretionary expenses; offset partially by

•a decrease of $20.9 million in optimization and marketing due primarily to a decrease of $24.2 million due to narrower location price differentials and lower optimization volumes and lower marketing earnings of $13.1 million due to lower earnings from purity NGL inventory sales and changes in the value of NGLs held in inventory, offset partially by an increase of $16.7 million due to wider product price differentials; and

•a decrease of $7.9 million from lower equity in net earnings from investments due primarily to lower volumes on Overland Pass Pipeline.

Adjusted EBITDA increased $107.9 million for the nine months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•an increase of $208.8 million in exchange services due primarily to $91.8 million in higher volumes in the Rocky Mountain region and Permian Basin, $83.6 million in lower costs due primarily to lower rail and pipeline transportation costs, $25.8 million related to lower unfractionated NGLs held in inventory, $24.1 million in higher average fee rates primarily in the Permian Basin, and $18.4 million in higher fees charged to customers with minimum volume obligations primarily in the Rocky Mountain region, offset partially by $21.8 million in lower volumes in the Mid-Continent region and $11.7 million in narrower product price differentials; and

•a decrease of $32.3 million in operating costs due primarily to reduced discretionary expenses; offset partially by

•a decrease of $113.9 million in optimization and marketing due primarily to a decrease of $75.4 million related to narrower location price differentials and lower optimization volumes, lower marketing earnings of $43.4 million due to lower earnings from purity NGL inventory sales and changes in the value of NGLs held in inventory; and

•a decrease of $18.3 million from lower equity in net earnings from investments due primarily to lower volumes on Overland Pass Pipeline.

The nine months ended September 30, 2020, includes $70.2 million of noncash impairment charges related to certain inactive assets and a $7.2 million noncash impairment charge related to our 50% investment in Chisholm Pipeline Company. For additional information on our impairment charges, see Note A of the Notes to Consolidated Financial Statements in this Quarterly Report.

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Capital expenditures decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to completed and paused capital-growth projects.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information	2020		2019		2020		2019
Raw feed throughput (MBbl/d) (a)	1,162		1,086		1,088		1,074
Average Conway-to-Mont Belvieu OPIS price differential - ethane in ethane/propane mix ($/gallon)	$	0.03	$	0.08	$	0.01	$	0.08

(a) - Represents physical raw feed volumes on which we charge a fee for transportation and/or fractionation services.

Volumes increased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to increased production at new and existing processing plants in the Rocky Mountain region and Permian Basin, offset partially by the unfavorable impact from producer curtailments primarily in the second quarter 2020. The three months ended September 30, 2020, was also favorably impacted by increased ethane volumes in the Mid-Continent region.

Natural Gas Pipelines

Overview - Our Natural Gas Pipelines segment, through its wholly owned assets, provides transportation and storage services to end users, such as natural gas distribution and electric-generation companies, that require natural gas to operate their businesses regardless of location price differentials. We have 50% ownership interests in Northern Border Pipeline and Roadrunner, which provide transportation services to various end users.

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

	Three Months Ended				Nine Months Ended				Three Months	Nine Months
	September 30,				September 30,				2020 vs. 2019	2020 vs. 2019
Financial Results	2020		2019		2020		2019		$ Increase (Decrease)	$ Increase (Decrease)
	(Millions of dollars)
Transportation revenues	$	96.4	$	102.4	$	303.1	$	296.2	(6.0)	6.9
Storage revenues	16.6		17.5		50.1		53.8		(0.9)	(3.7)
Residue natural gas sales and other revenues	4.3		1.6		6.9		5.5		2.7	1.4
Cost of sales and fuel (exclusive of depreciation and operating costs)	(3.4)		(0.4)		(5.1)		(3.8)		3.0	1.3
Operating costs, excluding noncash compensation adjustments	(33.4)		(38.6)		(99.0)		(108.1)		(5.2)	(9.1)
Equity in net earnings from investments	30.1		23.5		78.3		70.4		6.6	7.9
Other	(0.8)		(2.2)		(2.1)		(3.0)		1.4	0.9
Adjusted EBITDA	$	109.8	$	103.8	$	332.2	$	311.0	6.0	21.2
Capital expenditures	$	13.0	$	27.8	$	40.5	$	77.9	(14.8)	(37.4)

See reconciliation of net income to adjusted EBITDA in the “Adjusted EBITDA” section.

Adjusted EBITDA increased $6.0 million for the three months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•an increase of $6.6 million from higher equity in net earnings from investments due primarily to additional transportation capacity contracted on Northern Border; and

•a decrease of $5.2 million in operating costs due primarily to lower materials and supplies expenses and employee-related costs; offset partially by

•a decrease of $5.4 million in transportation services due primarily to lower interruptible revenue.

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Adjusted EBITDA increased $21.2 million for the nine months ended September 30, 2020, compared with the same period in 2019, primarily as a result of the following:

•a decrease of $9.1 million in operating costs due primarily to lower materials and supplies expenses and employee-related costs;

•an increase of $7.9 million from higher equity in net earnings from investments due primarily to additional transportation capacity contracted on Northern Border; and

•an increase of $6.4 million in transportation services due primarily to higher firm transportation revenue and a $13.5 million contract settlement, offset partially by lower interruptible revenue; offset partially by

•a decrease of $3.4 million from storage services due primarily to lower park and loan activity.

Capital expenditures decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due primarily to the completion of our expansion projects in 2019.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Operating Information (a)	2020		2019		2020		2019
Natural gas transportation capacity contracted (MDth/d)	7,349		7,628		7,485		7,568
Transportation capacity contracted	94	%	98	%	96	%	98	%

(a) - Includes volumes for consolidated entities only.

Natural gas transportation capacity contracted decreased for the three and nine months ended September 30, 2020, compared with the same periods in 2019, due to a contract settlement and the impact of current market conditions on demand for our services.

Roadrunner, in which we have a 50% ownership interest, has contracted all of its westbound capacity through 2041.

Northern Border Pipeline, in which we have a 50% ownership interest, has contracted substantially all of its long-haul transportation capacity through the fourth quarter 2020.

In June 2019, our subsidiary, Viking Gas Transmission Company (Viking), filed a proposed change in rates pursuant to Section 4 of the Natural Gas Act with the FERC. In February 2020, Viking filed a Stipulation and Offer of Settlement (Settlement) with the FERC for approval. The FERC accepted the Settlement in July 2020, which will not impact materially our results of operations.

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, allowance for equity funds used during construction, noncash compensation expense and other noncash items. We believe this non-GAAP financial measure is useful to investors because it and 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 financial performance among companies in our industry. Adjusted EBITDA should not be considered an alternative to net income, earnings per share or any other measure of financial performance presented in accordance with GAAP. Additionally, this calculation may not be comparable with similarly titled measures of other companies.

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The following table sets forth a reconciliation of net income, the nearest comparable GAAP financial performance measure, to adjusted EBITDA for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
Reconciliation of net income to adjusted EBITDA	(Thousands of dollars)
Net income	$	312,316	$	309,155	$	304,780	$	958,326
Add:
Interest expense, net of capitalized interest	176,371		129,577		535,955		362,490
Depreciation and amortization	153,245		121,430		426,014		350,552
Income tax expense	106,555		97,365		94,300		274,234
Impairment charges	—		—		641,754		—
Noncash compensation expense (a)	1,606		9,757		1,261		20,412
Equity AFUDC and other noncash items	(3,084)		(17,532)		(22,346)		(46,357)
Adjusted EBITDA	$	747,009	$	649,752	$	1,981,718	$	1,919,657
Reconciliation of segment adjusted EBITDA to adjusted EBITDA
Segment adjusted EBITDA:
Natural Gas Gathering and Processing	$	183,148	$	175,292	$	431,545	$	514,159
Natural Gas Liquids	451,243		367,462		1,199,801		1,091,863
Natural Gas Pipelines	109,837		103,819		332,194		311,011
Other (b)	2,781		3,179		18,178		2,624
Adjusted EBITDA	$	747,009	$	649,752	$	1,981,718	$	1,919,657

(a) - The three and nine months ended September 30, 2020, include a benefit of $2.4 million and $16.9 million related to the mark-to-market of ONEOK’s share-based deferred compensation plan.

(b) - The three and nine months ended September 30, 2020, include corporate gains of $2.2 million and $22.2 million, respectively, on extinguishment of debt related to open market repurchases.

CONTINGENCIES

See Note J of the Notes to Consolidated Financial Statements in this Quarterly Report for discussion of our legal proceedings.

LIQUIDITY AND CAPITAL RESOURCES

General - Our primary sources of cash inflows are operating cash flows, proceeds from our commercial paper program and our $2.5 Billion Credit Agreement, debt issuances and the issuance of common stock for our liquidity and capital resources requirements. In addition, we expect cash outflows for the remainder of 2020 to be primarily related to dividends paid to shareholders and interest.

We expect our sources of cash inflows to provide sufficient resources to finance our operations and quarterly cash dividends. We believe we have sufficient liquidity in this challenging market environment due to our $2.5 Billion Credit Agreement, which expires in June 2024, cash on hand from our June 2020 equity issuance and access to $1.0 billion available through our “at-the-market” equity program.

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

Guarantees and Cash Management - In March 2020, the SEC amended Rule 3-10 of Regulation S-X and created Rule 13-01 to simplify disclosure requirements related to certain registered securities. We and ONEOK Partners are issuers of certain public debt securities. We guarantee certain indebtedness of ONEOK Partners, and ONEOK Partners and the Intermediate Partnership guarantee certain of our indebtedness. The guarantees in place for our and ONEOK Partners’ indebtedness are full, irrevocable, unconditional and absolute joint and several guarantees to the holders of each series of outstanding securities. Liabilities under the guarantees rank equally in right of payment with all existing and future senior unsecured indebtedness. As ONEOK Partners and the Intermediate Partnership are consolidated subsidiaries of ONEOK, separate financial statements for the guarantors are not required, as long as the alternative disclosure required by Rule 13-01 is provided, which includes narrative disclosure and summarized information. The Intermediate Partnership holds all of ONEOK Partners’ interests and equity in its subsidiaries, which are non-guarantors. We do not have any material assets other than our ownership of all the

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interests in ONEOK Partners and substantially all the assets and operations reside with non-guarantor operating subsidiaries. Therefore, as allowed under Rule 13-01, we have excluded the summarized financial information for each issuer and guarantor.

We use a centralized cash management program that concentrates the cash assets of our non-guarantor operating subsidiaries in joint accounts for the purposes of providing financial flexibility and lowering the cost of borrowing, transaction costs and bank fees. Our centralized cash management program provides that funds in excess of the daily needs of our operating subsidiaries are concentrated, consolidated or otherwise made available for use by other entities within our consolidated group. Our operating subsidiaries participate in this program to the extent they are permitted pursuant to FERC regulations or their operating agreements. Under the cash management program, depending on whether a participating subsidiary has short-term cash surpluses or cash requirements, we provide cash to the subsidiary or the subsidiary provides cash to us.

Short-term Liquidity - Our principal sources of short-term liquidity consist of cash generated from operating activities, distributions received from our equity-method investments, proceeds from our commercial paper program and our $2.5 Billion Credit Agreement. As of September 30, 2020, we are in compliance with all covenants of the $2.5 Billion Credit Agreement.

At September 30, 2020, we had no borrowings under our $2.5 Billion Credit Agreement and $447.1 million of cash and cash equivalents.

As of September 30, 2020, we had a working capital surplus of $627.2 million (defined as current assets less current liabilities). Generally, our working capital is influenced by several factors, including, among other things: (i) the timing of (a) debt and equity issuances, (b) the funding of capital expenditures, (c) scheduled debt payments, and (d) the collection and payment of accounts receivable and payable; and (ii) the volume and cost of inventory and commodity imbalances. We may have working capital deficits in future periods as we continue to repay long-term debt and finance our capital-growth projects.

For additional information on our $2.5 Billion Credit Agreement, see Note D of the Notes to Consolidated Financial Statements in this Quarterly Report.

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

Debt Issuances - In May 2020, we completed an underwritten public offering of $1.5 billion senior unsecured notes consisting of $600 million, 5.85% senior notes due 2026; $600 million, 6.35% senior notes due 2031; and $300 million, 7.15% senior notes due 2051. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.48 billion. A portion of the proceeds were used to repay the outstanding borrowings under our $1.5 Billion Term Loan Agreement. The remainder was used for general corporate purposes.

In March 2020, we completed an underwritten public offering of $1.75 billion senior unsecured notes consisting of $400 million, 2.2% senior notes due 2025; $850 million, 3.1% senior notes due 2030; and $500 million, 4.5% senior notes due 2050. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.73 billion. A portion of the proceeds were used to pay all outstanding amounts under our commercial paper program. The remainder was used for general corporate purposes, which included repayment of other existing indebtedness and funding capital expenditures.

Debt Repayments - In May 2020, we repaid the remaining $1.25 billion of our $1.5 Billion Term Loan Agreement with cash on hand from our May 2020 public offering of $1.5 billion senior unsecured notes.

During the three and nine months ended September 30, 2020, we repurchased in the open market outstanding principal of certain of our senior notes in the amounts of $28.0 million and $202.3 million, respectively, for an aggregate repurchase price of $25.4 million and $177.7 million, respectively, with cash on hand. In connection with these open market repurchases, we recognized $2.2 million and $22.2 million of gains on extinguishment of debt, which is included in other income in our Consolidated Statement of Income for the three and nine months ended September 30, 2020, respectively. We may continue to repurchase debt securities issued by us and our affiliates in the future through open market purchases, privately negotiated transactions, tender offers, exchange offers, or otherwise, upon such terms and at such prices as we may from time to time determine for cash or other consideration.

For additional information on our long-term debt, see Note D of the Notes to Consolidated Financial Statements in this Quarterly Report.

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Equity Issuances - In July 2020, we established an “at-the-market” equity program for the offer and sale from time to time of our common stock up to an aggregate offering price of $1.0 billion. The program allows us to offer and sell common stock at prices we deem appropriate through a sales agent, in forward sales transactions through a forward seller or directly to one or more of the program’s managers acting as principals. Sales of our common stock may be made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. No shares have been sold through our “at-the-market” program as of the date of this report.

In June 2020, we completed an underwritten public offering of 29.9 million shares of our common stock at a public offering price of $32.00 per share, generating net proceeds, after deducting underwriting discounts, commissions and offering expenses, of $937.0 million. A portion of the proceeds were, and we anticipate the remainder will be, used for general corporate purposes, including repayment of existing indebtedness and funding capital expenditures.

Capital Expenditures - We classify expenditures that are expected to generate additional revenue, return on investment or significant operating efficiencies as capital-growth expenditures. Maintenance capital expenditures are those capital expenditures required to maintain our existing assets and operations and do not generate additional revenues. Maintenance capital expenditures are made to replace partially or fully depreciated assets, to maintain the existing operating capacity of our assets and to extend their useful lives. Our capital expenditures are financed typically through operating cash flows and short- and long-term debt.

Capital expenditures, excluding AFUDC and capitalized interest, were $1.9 billion and $2.7 billion for the nine months ended September 30, 2020 and 2019, respectively.

We expect our remaining 2020 capital expenditures to be funded with cash on hand. Excluding our paused and suspended projects, we have completed all of our announced capital-growth projects. See discussion in the “Recent Developments” section.

Credit Ratings - Our long-term debt credit ratings as of October 19, 2020, are shown in the table below:

Rating Agency	Long-Term Rating	Short-Term Rating	Outlook
Moody’s	Baa3	Prime-3	Stable
S&P	BBB	A-2	Stable

Our credit ratings, which are investment grade, may be affected by a material change in our financial ratios or a material event affecting our business and industry. Although we are in the midst of a challenging market environment, our credit ratings have not been materially affected. The most common criteria for assessment of our credit ratings are the debt-to-EBITDA ratio, interest coverage, business risk profile and liquidity. If our credit ratings were downgraded, our cost to borrow funds under our $2.5 Billion Credit Agreement would increase and a potential loss of access to the commercial paper market could occur. In the event that we are unable to borrow funds under our commercial paper program and there has not been a material adverse change in our business, we would continue to have access to our $2.5 Billion Credit Agreement, which expires in 2024. An adverse credit rating change alone is not a default under our $2.5 Billion Credit Agreement.

In the normal course of business, our counterparties provide us with secured and unsecured credit. In the event of a downgrade in our credit ratings or a significant change in our counterparties’ evaluation of our creditworthiness, we 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. We may be required to fund margin requirements with our counterparties with cash, letters of credit or other negotiable instruments.

Dividends - Holders of our common stock share equally in any common stock dividends declared by our Board of Directors, subject to the rights of the holders of outstanding preferred stock. In February 2020, May 2020 and August 2020 we paid a dividend of $0.935 per share ($3.74 per share on an annualized basis). A dividend of $0.935 per share was declared for the shareholders of record at the close of business on November 2, 2020, payable November 13, 2020.

Our Series E Preferred Stock pays 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% per year. We paid dividends for the Series E Preferred Stock of $0.3 million in February 2020, May 2020 and August 2020. Dividends totaling $0.3 million were declared for the Series E Preferred Stock and are payable November 13, 2020.

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For the nine months ended September 30, 2020, our cash dividends paid exceeded our cash flows from operations by $86.4 million, primarily resulting from the effects of the market conditions that began in March 2020 and the resulting impact of producer curtailments on our cash flows. As a result, we utilized cash on hand from other sources of short- and long-term liquidity to fund a portion of our dividends. We expect the improved volumes and cash flows experienced in the third quarter 2020 to continue for the remainder of the year and into 2021. However, cash dividends paid may exceed our cash flows from operations for the year ending December 31, 2020, and therefore, we may continue to utilize cash on hand from other sources of short- and long-term liquidity to fund a small portion of our dividends.

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 can include depreciation and amortization, impairment charges, allowance for equity funds used during construction, gain or loss on sale of assets, deferred income taxes, net undistributed earnings from equity-method investments, 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
	Nine Months Ended				2020 vs. 2019
	September 30,				Favorable (Unfavorable)
	2020		2019
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	1,103.1	$	1,326.8	$	(223.7)
Investing activities	(1,981.9)		(2,647.9)		666.0
Financing activities	1,304.9		1,982.4		(677.5)
Change in cash and cash equivalents	426.1		661.3		(235.2)
Cash and cash equivalents at beginning of period	21.0		12.0		9.0
Cash and cash equivalents at end of period	$	447.1	$	673.3	$	(226.2)

Operating Cash Flows - Operating cash flows are affected by earnings from our business activities and changes in our operating assets and liabilities. Changes in commodity prices and demand for our services or products, whether because of general economic conditions, changes in supply, changes in demand for the end products that are made with our products or increased competition from other service providers, could affect our earnings and operating cash flows. Our operating cash flows can also be impacted by changes in our NGLs and natural gas inventory balances, which are driven primarily by commodity prices, supply, demand and the operation of our assets.

Cash flows from operating activities, before changes in operating assets and liabilities for the nine months ended September 30, 2020, decreased $116.3 million compared with the same period in 2019. This decrease is due primarily to higher interest expense, lower volumes and lower realized prices in our Natural Gas Gathering and Processing segment and lower optimization and marketing earnings in our Natural Gas Liquids segment. These decreases were offset partially by an increase in exchange services due to higher volumes and lower rail and pipeline transportation costs in our Natural Gas Liquids segment and lower operating costs across our segments, as discussed in “Financial Results and Operating Information.”

The changes in operating assets and liabilities decreased operating cash flows $346.6 million for the nine months ended September 30, 2020, compared with a decrease of $239.2 million for the same period in 2019. This change is due primarily to changes in 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 changes in risk-management assets and liabilities, which include a loss on the settlement of $750 million of our forward-starting interest-rate swaps related to our March 2020 issuance of senior unsecured notes and changes in the fair value of risk-management assets and liabilities, which vary from period to period and with changes in commodity prices and interest rates.

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Investing Cash Flows - Cash used in investing activities for the nine months ended September 30, 2020, decreased $666.0 million, compared with the same period in 2019, due primarily to reduced capital expenditures related to our completed, paused and suspended capital-growth projects.

Financing Cash Flows - Cash from financing activities for the nine months ended September 30, 2020, decreased $677.5 million, compared with the same period in 2019, due primarily to the issuance of $3.2 billion in long-term debt in 2020, compared with $4.2 billion long-term debt issuances in 2019, the repayment of long-term debt and short-term borrowings and increased dividends, offset partially by the issuance of common stock in June 2020.

REGULATORY, ENVIRONMENTAL AND SAFETY MATTERS

Environmental Matters - We are subject to a variety of historical preservation and environmental laws and/or regulations that affect many aspects of our 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 and waterways preservation, wildlife conservation, cultural resources protection, hazardous materials transportation, and pipeline and facility construction. These laws and regulations require us 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 us to fines, penalties, reputational harm and/or interruptions in our operations that could be material to our results of operations or financial condition. For example, if a leak or spill of hazardous substances or petroleum products occurs from pipelines or facilities that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including response, investigation and cleanup costs, which could affect adversely 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 our 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 us.

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 flows and projected levels of dividends), liquidity, management’s plans and objectives for our future capital-growth projects and other future operations (including plans to construct additional natural gas and NGL pipelines, processing and fractionation 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.

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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,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “guidance,” “intend,” “may,” “might,” “outlook,” “plan,” “potential,” “project,” “scheduled,” “should,” “will,” “would” 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 impact on drilling and production by factors beyond our control, including the demand for natural gas and crude oil; producers’ desire and ability to drill and obtain necessary permits; regulatory compliance; reserve performance; and capacity constraints and/or shut downs on the pipelines that transport crude oil, natural gas and NGLs from producing areas and our facilities;

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

•the length, severity and reemergence of a pandemic or other health crisis, such as the recent outbreak of COVID-19 and the measures that international, federal, state and local governments, agencies, law enforcement and/or health authorities implement to address it, which may (as with COVID-19) precipitate or exacerbate one or more of the factors herein, reduce the demand for natural gas, NGLs and crude oil and significantly disrupt or prevent us and our customers and counterparties from operating in the ordinary course for an extended period and increase the cost of operating our business;

•the timing and extent of changes in energy commodity prices, including changes due to production decisions by other countries, such as the failure of countries to abide by recent agreements to reduce production volumes;

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

•risks associated with adequate supply to our gathering, processing, fractionation and pipeline facilities, including production declines that outpace new drilling, the shutting-in of production by producers, actions taken by federal, state or local governments to require producers to prorate or to cut their production levels as a way to address any excess market supply situations or extended periods of ethane rejection;

•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;

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

•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 United States natural gas and crude oil; and

–    availability of additional storage capacity;

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

•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 throughout the world;

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

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

•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;

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

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

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•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;

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

•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, production limits and authorized rates of recovery of natural gas and natural gas transportation costs;

•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 results of administrative proceedings and litigation, regulatory actions, executive orders, 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 the CFTC;

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

•the capital-intensive nature of our businesses;

•the mechanical integrity of facilities operated;

•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 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 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 and guarantee obligations 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 our credit;

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

•the impact and outcome of pending and future litigation;

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

•our ability to control operating costs and make cost-saving changes;

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

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

•the risk inherent in the use of information systems in our respective businesses and those of our counterparties and service providers, including cyber-attacks, which, according to experts, have increased in volume and sophistication since the beginning of the COVID-19 pandemic; implementation of new software and hardware; and the impact on the timeliness of information for financial reporting;

•operational challenges relating to the COVID-19 pandemic and efforts to mitigate the spread of the virus, including logistical challenges, protecting the health and well-being of our employees, remote work arrangements, performance of contracts and supply chain disruptions;

•the impact of potential impairment charges; 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 affect adversely our future results. These and other risks are described in greater detail in Part I, Item 1A, Risk Factors, in our Annual Report 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 exposure to market risk discussed below includes forward-looking statements and represents an estimate of possible changes in future earnings that could occur assuming hypothetical future movements in interest rates or commodity prices. Our views on market risk are not necessarily indicative of actual results that may occur and do not represent the maximum possible

53

gains and losses that may occur since actual gains and losses will differ from those estimated based on actual fluctuations in interest rates or commodity prices and the timing of transactions.

We are exposed to market risk due to commodity price and interest-rate volatility. Market risk is the risk of loss arising from adverse changes in market rates and prices. We may use financial instruments, including forward sales, swaps, options and futures, to manage the risks of certain identifiable or anticipated transactions and achieve more predictable cash flows. Our risk-management function follows established policies and procedures to monitor our natural gas, condensate and NGL marketing activities and interest rates to ensure our hedging activities mitigate market risks. We do not use financial instruments for trading purposes.

COMMODITY PRICE RISK

As part of our hedging strategy, we use commodity derivative financial instruments and physical-forward contracts described in Note C of the Notes to Consolidated Financial Statements in this Quarterly Report to reduce the impact of near-term price fluctuations of natural gas, NGLs and condensate.

Although our businesses are primarily fee-based, in our Natural Gas Gathering and Processing segment, we are exposed to commodity price risk as a result of retaining a portion of the commodity sales proceeds associated with our POP with fee contracts. Under certain POP with fee contracts, our contractual fees and POP percentage may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. We are exposed to basis risk between the various production and market locations where we buy and sell commodities.

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

	Three Months Ending December 31, 2020
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	9.5	$	0.55	/ gallon	70%
Condensate (MBbl/d) - WTI-NYMEX	2.2	$	53.67	/ Bbl	92%
Natural gas (BBtu/d) - NYMEX and basis	108.3	$	2.36	/ MMBtu	89%

	Year Ending December 31, 2021
	Volumes Hedged	Average Price			Percentage Hedged
NGLs - excluding ethane (MBbl/d) - Conway/Mont Belvieu	5.1	$	0.48	/ gallon	29%
Condensate (MBbl/d) - WTI-NYMEX	0.7	$	44.55	/ Bbl	19%
Natural gas (BBtu/d) - NYMEX and basis	84.8	$	2.55	/ MMBtu	54%

Our 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, 2020. Condensate sales are typically based on the price of crude oil. Assuming normal operating conditions, we estimate the following for our forecasted equity volumes:

•a $0.01 per-gallon change in the composite price of NGLs, excluding ethane, would change adjusted EBITDA for the three months ending December 31, 2020, and for the year ending December 31, 2021, by approximately $0.5 million and $2.7 million, respectively;

•a $1.00 per-barrel change in the price of crude oil would change adjusted EBITDA for the three months ending December 31, 2020, and for the year ending December 31, 2021, by approximately $0.2 million and $1.4 million, respectively; and

•a $0.10 per-MMBtu change in the price of residue natural gas would change adjusted EBITDA for the three months ending December 31, 2020, and for the year ending December 31, 2021, by approximately $1.1 million and $5.8 million, respectively.

These estimates do not include any effects of hedging or effects on demand for our 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.

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INTEREST-RATE RISK

We are exposed to interest-rate risk through borrowings under our $2.5 Billion Credit Agreement, commercial paper program and long-term debt issuances. Future increases in commercial paper rates or bond rates could expose us to increased interest costs on future borrowings. 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. In March 2020, we settled $750 million of our forward-starting interest-rate swaps related to our underwritten public offerings of $1.75 billion senior unsecured notes. In May 2020, we settled the remaining $1.3 billion of our interest-rate swaps used to hedge our LIBOR-based interest payments.

At September 30, 2020, and December 31, 2019, we had forward-starting interest-rate swaps with notional amounts totaling $1.1 billion and $1.8 billion, respectively, to hedge the variability of interest payments on a portion of our forecasted debt issuances. At December 31, 2019, we had interest-rate swaps with notional amounts totaling $1.3 billion to hedge the variability of our LIBOR-based interest payments, all of which have settled as of September 30, 2020. All of our interest-rate swaps are designated as cash flow hedges.

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

COUNTERPARTY CREDIT RISK

We assess the creditworthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. Certain of our counterparties may be impacted by a relatively low commodity price environment and could experience financial problems, which could result in nonpayment and/or nonperformance, which could impact adversely our results of operations.

The creditworthiness of our counterparties, which are primarily investment grade, and our customer concentration are consistent with those discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures about Market Risk, in our Annual Report.

ITEM 4.CONTROLS AND PROCEDURES

Quarterly Evaluation of Disclosure Controls and Procedures - Our Chief Executive Officer (Principal Executive Officer) and Chief Financial Officer (Principal Financial Officer) have concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report based on the evaluation of the controls and procedures required by Rules 13a-15(e) and 15d-15(e) 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, 2020, 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

Additional information about our legal proceedings is included in Note J of the Notes to Consolidated Financial Statements in this Quarterly Report and under Note N of the Notes to Consolidated Financial Statements in our Annual Report.

ITEM 1A.RISK FACTORS

The COVID-19 pandemic and recent energy industry developments have affected adversely, and could continue to affect adversely, our results of operations.

The COVID-19 pandemic has led to global and regional economic disruption, volatility in the financial markets and a weakened commodity price environment. The outbreak and government measures taken in response, including extended quarantines, closures and reduced operations of businesses have also had a significant adverse impact, both direct and indirect, on our business and the economy. Due to reductions in economic activity, the world is experiencing reduced demand for refined products, NGLs and natural gas, and weakened commodity prices, which has affected adversely our operations. Continuing uncertainty regarding the global impact of the COVID-19 impact is likely to result in reduced demand for the services we provide. We may also experience disruptions to supply chains and the availability and efficiency of our workforce as a result of

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the pandemic, which could affect adversely our ability to conduct our business and operations. Moreover, the uncertainty regarding the duration and long-term impact of the COVID-19 pandemic could further impact our access to capital markets. The spread of COVID-19 may also cause other unpredictable or unforeseen events that may affect adversely our results of operations.

Volatility in commodity prices may continue to have an impact on many of our counterparties, which, in turn, could have a negative impact on their ability to meet their obligations to us. For example, in March 2020, unsuccessful negotiations between the Organization of the Petroleum Exporting Countries (OPEC) and Russia regarding crude oil production cuts resulted in a price war between Saudi Arabia and Russia. As a result, the global supply of crude oil significantly exceeded demand and led to a collapse in crude oil prices. However, further negotiations in April 2020 resulted in an agreement to reduce production volumes. Failure to abide by these agreed-upon crude oil production cuts may further destabilize the global oil market, which is simultaneously experiencing a limitation on crude oil storage capacity and a dramatic decrease in demand due to COVID-19, and crude oil prices may continue to decline. Recently, OPEC and Russia agreed to an ease in crude oil production cuts, and these increased volumes could further negatively impact our counterparties. If adverse global or regional economic and market conditions remain uncertain or persist, spread or deteriorate further, we may continue to experience an adverse impact on our business, results of operations, financial position, cash flows and/or liquidity.

Our investors should consider additional risks set forth in Part I, Item 1A, Risk Factors, of our Annual Report that could affect us and our business. Additionally, the impact of the COVID-19 pandemic could exacerbate many of the risks identified in our Annual Report. 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. Even after the COVID-19 pandemic has moderated and business and social distancing restrictions have eased, we may continue to experience similar adverse effects to our businesses, operating results, cash flows and/or financial condition resulting from economic slowdown that is expected to persist. 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 consider carefully the discussion of risks and the other information included or incorporated by reference in this Quarterly Report, including “Forward-Looking Statements,” which are included in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

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

Not applicable.

ITEM 3.DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4.MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.OTHER INFORMATION

Not applicable.

ITEM 6.EXHIBITS

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

or providing any factual disclosures about us, any other persons, any state of affairs or other matters.

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

Exhibit No.	Exhibit Description
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 September 20, 2018 (File No. 1-13643)).
3.2	Amended and Restated Certificate of Incorporation of ONEOK, Inc., dated July 3, 2017, as amended (incorporated by reference from Exhibit 3.2 to ONEOK Inc.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2017, filed November 1, 2017 (File No. 1-13643)).
10.1	Equity Distribution Agreement, dated July 23, 2020, among ONEOK, Inc., and Credit Suisse Securities (USA) LLC, BofA Securities, Inc., Goldman Sachs & Co. LLC, Mizuho Securities USA LLC, Morgan Stanley & Co. LLC, RBC Capital Markets, LLC, Scotia Capital (USA) Inc., SMBC Nikko Securities America, Inc., SunTrust Robinson Humphrey, Inc. and TD Securities (USA) LLC as sales agents, principals and/or forward sellers, and Credit Suisse Capital LLC, Bank of America, N.A., Goldman Sachs & Co. LLC, Mizuho Markets Americas LLC, Morgan Stanley & Co. LLC, Royal Bank of Canada, The Bank of Nova Scotia and The Toronto-Dominion Bank as forward purchasers (incorporated by reference from Exhibit 1.1 to ONEOK, Inc.’s Current Report on Form 8-K with a filing date of July 24, 2020 (File No. 1-13643)).
10.2	Form of Master Forward Confirmation (incorporated by reference from Exhibit 1.2 to ONEOK Inc.’s Current Report on Form 8-K with a filing date of July 24, 2020 (File No. 1-13643)).
22.1	List of subsidiary guarantors and issuers of guaranteed securities.
31.1	Certification of Terry K. Spencer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Walter S. Hulse III 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 Walter S. Hulse III 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	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	Inline XBRL Taxonomy Extension Schema Document.
101.CAL	Inline XBRL Taxonomy Calculation Linkbase Document.
101.DEF	Inline XBRL Taxonomy Extension Definitions Document.
101.LAB	Inline XBRL Taxonomy Label Linkbase Document.
101.PRE	Inline XBRL Taxonomy Presentation Linkbase Document.
104	Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibit 101).

Attached as Exhibit 101 to this Quarterly Report are the following Inline XBRL-related documents: (i) Document and Entity Information; (ii) Consolidated Statements of Income for the three and nine months ended September 30, 2020 and 2019; (iii) Consolidated Statements of Comprehensive Income for the three and nine months ended September 30, 2020 and 2019; (iv) Consolidated Balance Sheets at September 30, 2020, and December 31, 2019; (v) Consolidated Statements of Cash Flows for the nine months ended September 30, 2020 and 2019; (vi) Consolidated Statements of Changes in Equity for the three and nine months ended September 30, 2020 and 2019; and (vii) Notes to Consolidated Financial Statements.

57

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: October 28, 2020	By:	/s/ Walter S. Hulse III
		Walter S. Hulse III
		Chief Financial Officer, Treasurer and
		Executive Vice President, Strategic Planning
		and Corporate Affairs
		(Principal Financial Officer)

58

EX-22.1

Exhibit 22.1

List of Subsidiary Guarantors and Issuers

of Guaranteed Securities

As of September 30, 2020, the following entities guarantee the notes issued by ONEOK, Inc. (the “ONEOK Notes”) and ONEOK Partners, L.P. (the “ONEOK Partners Notes”).

Entity	Jurisdiction of Incorporation or Organization	ONEOK Notes	ONEOK Partners Notes
ONEOK, Inc.	Oklahoma	Issuer	Guarantor
ONEOK Partners, L.P.	Delaware	Guarantor	Issuer
ONEOK Partners Intermediate Limited Partnership	Delaware	Guarantor	Guarantor

As of September 30, 2020, the ONEOK Notes consisted of the following securities:

Issued under the Indenture dated as of September 24, 1998

6-7/8% Debentures due 2028

Issued under the Indenture dated as of December 28, 2001

6.00% Notes due 2035

Issued under the Indenture dated as of January 26, 2012

4.25% Notes due 2022

7.50% Notes due 2023

2.75% Notes due 2024

2.200% Notes due 2025

5.850% Notes due 2026

4.000% Notes due 2027

4.55% Notes due 2028

4.35% Notes due 2029

3.40% Notes due 2029

3.100% Notes due 2030

6.350% Notes due 2031

4.950% Notes due 2047

5.20% Notes due 2048

4.45% Notes due 2049

4.500% Notes due 2050

7.150% Notes due 2051

As of September 30, 2020, the ONEOK Partners Notes consisted of the following securities:

Issued under the Indenture dated as of September 25, 2006

3.375% Senior Notes due 2022

5.000% Senior Notes due 2023

4.90% Senior Notes due 2025

6.65% Senior Notes due 2036

6.85% Senior Notes due 2037

6.125% Senior Notes due 2041

6.200% Senior Notes due 2043

EX-31.1

Exhibit 31.1

Certification

I, Terry K. Spencer, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: October 28, 2020

/s/ Terry K. Spencer

Terry K. Spencer

Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Walter S. Hulse III, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: October 28, 2020

/s/ Walter S. Hulse III

Walter S. Hulse III

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of ONEOK, Inc. (the “Registrant”) for the period ending September 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Terry K. Spencer, Chief Executive Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ Terry K. Spencer

Terry K. Spencer

Chief Executive Officer

October 28, 2020

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

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of ONEOK, Inc. (the “Registrant”) for the period ending September 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Walter S. Hulse III, Chief Financial Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

/s/ Walter S. Hulse III

Walter S. Hulse III

Chief Financial Officer

October 28, 2020

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

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2020	Oct. 19, 2020
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity File Number	001-13643
Entity Registrant Name	ONEOK, Inc.
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-1520922
Entity Address, Address Line One	100 West Fifth Street,
Entity Address, City or Town	Tulsa,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74103
City Area Code	918
Local Phone Number	588-7000
Title of 12(b) Security	Common stock, par value of $0.01
Trading Symbol	OKE
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		444,397,414
Entity Central Index Key	0001039684
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Amendment Flag	false

XML

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenues
Revenues	$ 2,174,264	$ 2,263,228	$ 5,971,665	$ 7,500,761
Cost of sales and fuel (exclusive of items shown separately below)	1,265,674	1,414,528	3,483,060	4,996,699
Operations and maintenance	173,548	218,305	538,782	632,332
Depreciation and amortization	153,245	121,430	426,014	350,552
Impairment charges (Note A)	0	0	604,024	0
General taxes	31,381	26,830	97,651	91,257
(Gain) loss on sale of assets	(17)	(16)	(560)	2,882
Operating income	550,433	482,151	822,694	1,427,039
Equity in net earnings from investments (Note I)	38,046	37,576	108,001	115,175
Impairment of equity investments (Note A)	0	0	(37,730)	0
Allowance for equity funds used during construction	3,084	15,792	22,347	45,175
Other income	8,175	6,643	34,390	21,685
Other expense	(4,496)	(6,065)	(14,667)	(14,024)
Interest expense (net of capitalized interest of $13,821, $27,610, $61,439 and $73,601, respectively)	(176,371)	(129,577)	(535,955)	(362,490)
Income before income taxes	418,871	406,520	399,080	1,232,560
Income taxes	(106,555)	(97,365)	(94,300)	(274,234)
Net income	312,316	309,155	304,780	958,326
Less: Preferred stock dividends	275	275	825	825
Net income available to common shareholders	$ 312,041	$ 308,880	$ 303,955	$ 957,501
Basic earnings per common share (Note G)	$ 0.70	$ 0.75	$ 0.71	$ 2.32
Diluted earnings per common share (Note G)	$ 0.70	$ 0.74	$ 0.71	$ 2.31
Average shares (thousands)
Basic	445,103	413,816	426,369	413,443
Diluted	445,510	415,578	426,997	415,277
Commodity Sales
Revenues
Revenues	$ 1,852,198	$ 1,947,834	$ 5,004,375	$ 6,567,634
Services
Revenues
Revenues	$ 322,066	$ 315,394	$ 967,290	$ 933,127

XML

CONSOLIDATED STATEMENT OF INCOME (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Interest expense (net of capitalized interest)	$ 13,821	$ 27,610	$ 61,439	$ 73,601

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Net income	$ 312,316	$ 309,155	$ 304,780	$ 958,326
Other comprehensive income (loss), net of tax
Change in fair value of derivatives, net of tax of $4,704, $22,050, $50,307 and $59,679, respectively	(15,750)	(73,822)	(168,421)	(199,795)
Derivative amounts reclassified to net income, net of tax of $(3,038), $2,673, $(3,360) and $8,654, respectively	5,361	(8,952)	11,210	(29,748)
Change in retirement and other postretirement benefit plan obligations, net of tax of $(1,064), $(737), $(3,192) and $(2,172), respectively	3,562	2,465	10,685	7,271
Other comprehensive income (loss) of unconsolidated affiliates, net of tax of $(332), $1,314, $3,015 and $3,164, respectively	1,112	(4,399)	(10,092)	(10,593)
Total other comprehensive loss, net of tax	(5,715)	(84,708)	(156,618)	(232,865)
Comprehensive income	$ 306,601	$ 224,447	$ 148,162	$ 725,461

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (PARANTHETICAL) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Change in fair value of derivatives, tax	$ 4,704	$ 22,050	$ 50,307	$ 59,679
Derivative amounts reclassified to net income, tax	(3,038)	2,673	(3,360)	8,654
Change in retirement and other postretirement benefit plan obligations, tax	(1,064)	(737)	(3,192)	(2,172)
Other comprehensive income (loss) of unconsolidated affiliates, tax	$ (332)	$ 1,314	$ 3,015	$ 3,164

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current assets
Cash and cash equivalents	$ 447,129	$ 20,958
Accounts receivable, net	717,852	835,121
Materials and supplies	158,950	201,749
NGLs and natural gas in storage	300,577	304,926
Commodity imbalances	13,289	25,267
Other current assets	83,565	82,313
Total current assets	1,721,362	1,470,334
Property, plant and equipment
Property, plant and equipment	22,803,167	22,051,492
Accumulated depreciation and amortization	3,773,852	3,702,807
Net property, plant and equipment	19,029,315	18,348,685
Investments and other assets
Investments in unconsolidated affiliates (Note A)	790,373	861,844
Goodwill and intangible assets (Note A)	776,330	957,833
Other assets	463,496	173,425
Total investments and other assets	2,030,199	1,993,102
Total assets	22,780,876	21,812,121
Current liabilities
Current maturities of long-term debt (Note D)	7,650	7,650
Short-term borrowings (Note D)	0	220,000
Accounts payable	624,483	1,209,900
Commodity imbalances	125,955	104,480
Accrued taxes	103,778	75,422
Accrued interest	140,506	190,750
Operating lease liability, current	13,646	1,883
Other current liabilities	78,124	210,213
Total current liabilities	1,094,142	2,020,298
Long-term debt, excluding current maturities (Note D)	14,249,339	12,479,757
Deferred credits and other liabilities
Deferred income taxes	582,334	536,063
Operating lease liability, noncurrent	90,806	13,509
Other deferred credits	618,143	536,543
Total deferred credits and other liabilities	1,291,283	1,086,115
Commitments and contingencies (Note J)
Equity (Note E)
Preferred stock, $0.01 par value: authorized and issued 20,000 shares at September 30, 2020, and December 31, 2019	0	0
Common stock, $0.01 par value: authorized 1,200,000,000 shares, issued 474,916,234 shares and outstanding 444,392,615 shares at September 30, 2020; issued 445,016,234 shares and outstanding 413,239,050 shares at December 31, 2019	4,749	4,450
Paid-in capital	7,448,484	7,403,895
Accumulated other comprehensive loss (Note F)	(530,618)	(374,000)
Retained earnings	0	0
Treasury stock, at cost: 30,523,619 shares at September 30, 2020, and 31,777,184 shares at December 31, 2019	(776,503)	(808,394)
Total equity	6,146,112	6,225,951
Total liabilities and equity	$ 22,780,876	$ 21,812,121

XML

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2020	Dec. 31, 2019
Equity (Note E)
Common stock, shares, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares, authorized (in shares)	1,200,000,000	1,200,000,000
Common stock, shares, issued (in shares)	474,916,234	445,016,234
Common stock, shares, outstanding (in shares)	444,392,615	413,239,050
Treasury stock, shares, (in shares)	30,523,619	31,777,184
Preferred stock, shares, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares, issued (in shares)	20,000	20,000

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Operating activities
Net income	$ 304,780	$ 958,326
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	426,014	350,552
Impairment charges	641,754	0
Equity in net earnings from investments	(108,001)	(115,175)
Distributions received from unconsolidated affiliates	109,595	121,176
Deferred income tax expense	93,174	269,488
Other, net	(17,599)	(18,337)
Changes in assets and liabilities:
Accounts receivable	111,629	100,250
NGLs and natural gas in storage	4,349	13,122
Accounts payable	(198,809)	(162,806)
Accrued interest	(50,244)	(39,314)
Risk-management assets and liabilities	(136,543)	(93,244)
Other assets and liabilities, net	(76,971)	(57,193)
Cash provided by operating activities	1,103,128	1,326,845
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(1,924,003)	(2,739,338)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	22,280	82,171
Other, net	(80,148)	9,293
Cash used in investing activities	(1,981,871)	(2,647,874)
Financing activities
Dividends paid	(1,189,575)	(1,079,379)
Repayment of short-term borrowings, net	(220,000)	0
Issuance of long-term debt, net of discounts	3,244,777	4,185,435
Debt financing costs	(28,324)	(29,777)
Repayment of long-term debt	(1,433,480)	(1,055,436)
Issuance of common stock	959,653	19,333
Other	(28,137)	(57,813)
Cash provided by financing activities	1,304,914	1,982,363
Change in cash and cash equivalents	426,171	661,334
Cash and cash equivalents at beginning of period	20,958	11,975
Cash and cash equivalents at end of period	$ 447,129	$ 673,309

XML

CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Common Stock	Preferred Stock	Paid-in Capital	Accumulated Other Comprehensive Loss	Retained Earnings (Accumulated Deficit)	Treasury Stock
Shares, issued, beginning balance at Dec. 31, 2018		445,016,234	20,000
Total equity, beginning balance at Dec. 31, 2018	$ 6,579,543	$ 4,450	$ 0	$ 7,615,138	$ (188,239)	$ 0	$ (851,806)
Net income	337,208	0	0	0	0	337,208	0
Other comprehensive loss	$ (81,285)	0	0	0	(81,285)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	0	0	0	0	(275)	0
Common Stock Issued During Period, Value, Other	$ 6,260	0	0	(24,779)	0	0	31,039
Common stock dividends paid (in dollars per share)	$ 0.86
Common Stock Dividends	$ (354,304)	0	0	(17,438)	0	(336,866)	0
Other, net	(45,074)	$ 0	$ 0	(45,074)	0	0	0
Shares, issued, ending balance at Mar. 31, 2019		445,016,234	20,000
Total equity, ending balance at Mar. 31, 2019	6,442,006	$ 4,450	$ 0	7,527,847	(269,524)	0	(820,767)
Shares, issued, beginning balance at Dec. 31, 2018		445,016,234	20,000
Total equity, beginning balance at Dec. 31, 2018	6,579,543	$ 4,450	$ 0	7,615,138	(188,239)	0	(851,806)
Net income	958,326
Other comprehensive loss	(232,865)
Shares, issued, ending balance at Sep. 30, 2019		445,016,234	20,000
Total equity, ending balance at Sep. 30, 2019	6,218,906	$ 4,450	$ 0	7,448,099	(421,104)	0	(812,539)
Shares, issued, beginning balance at Mar. 31, 2019		445,016,234	20,000
Total equity, beginning balance at Mar. 31, 2019	6,442,006	$ 4,450	$ 0	7,527,847	(269,524)	0	(820,767)
Net income	311,963	0	0	0	0	311,963	0
Other comprehensive loss	$ (66,872)	0	0	0	(66,872)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	0	0	0	0	(275)	0
Common Stock Issued During Period, Value, Other	$ 11,726	0	0	6,335	0	0	5,391
Common stock dividends paid (in dollars per share)	$ 0.865
Common Stock Dividends	$ (357,416)	0	0	(45,728)	0	(311,688)	0
Other, net	7,004	$ 0	$ 0	7,004	0	0	0
Shares, issued, ending balance at Jun. 30, 2019		445,016,234	20,000
Total equity, ending balance at Jun. 30, 2019	6,348,136	$ 4,450	$ 0	7,495,458	(336,396)	0	(815,376)
Net income	309,155	0	0	0	0	309,155	0
Other comprehensive loss	$ (84,708)	0	0	0	(84,708)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	0	0	0	0	(275)	0
Common Stock Issued During Period, Value, Other	$ 7,075	0	0	4,238	0	0	2,837
Common stock dividends paid (in dollars per share)	$ 0.89
Common Stock Dividends	$ (367,840)	0	0	(58,960)	0	(308,880)	0
Other, net	7,363	$ 0	$ 0	7,363	0	0	0
Shares, issued, ending balance at Sep. 30, 2019		445,016,234	20,000
Total equity, ending balance at Sep. 30, 2019	6,218,906	$ 4,450	$ 0	7,448,099	(421,104)	0	(812,539)
Shares, issued, beginning balance at Dec. 31, 2019		445,016,234	20,000
Total equity, beginning balance at Dec. 31, 2019	6,225,951	$ 4,450	$ 0	7,403,895	(374,000)	0	(808,394)
Net income	(141,857)	0	0	0	0	(141,857)	0
Other comprehensive loss	$ (125,386)	0	0	0	(125,386)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	$ 0	0	(275)	0	0	0
Common Stock Issued During Period, Shares, Other		0
Common Stock Issued During Period, Value, Other	$ 7,089	$ 0	0	(9,286)	0	0	16,375
Common stock dividends paid (in dollars per share)	$ 0.935
Common Stock Dividends	$ (386,931)	0	0	(386,931)	0	0	0
Other, net	(17,950)	$ 0	$ 0	(17,950)	0	0	0
Shares, issued, ending balance at Mar. 31, 2020		445,016,234	20,000
Total equity, ending balance at Mar. 31, 2020	5,560,641	$ 4,450	$ 0	6,989,453	(499,386)	(141,857)	(792,019)
Shares, issued, beginning balance at Dec. 31, 2019		445,016,234	20,000
Total equity, beginning balance at Dec. 31, 2019	6,225,951	$ 4,450	$ 0	7,403,895	(374,000)	0	(808,394)
Net income	304,780
Other comprehensive loss	(156,618)
Shares, issued, ending balance at Sep. 30, 2020		474,916,234	20,000
Total equity, ending balance at Sep. 30, 2020	6,146,112	$ 4,749	$ 0	7,448,484	(530,618)	0	(776,503)
Cumulative effect adjustment for adoption of ASU 2016-02, “Leases (Topic 842)”	(67)	$ 0	$ 0	0	0	(67)	0
Shares, issued, beginning balance at Mar. 31, 2020		445,016,234	20,000
Total equity, beginning balance at Mar. 31, 2020	5,560,641	$ 4,450	$ 0	6,989,453	(499,386)	(141,857)	(792,019)
Net income	134,321	0	0	0	0	134,321	0
Other comprehensive loss	$ (25,517)	0	0	0	(25,517)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	$ 0	0	(275)	0	0	0
Common Stock Issued During Period, Shares, Other		29,900,000
Common Stock Issued During Period, Value, Other	$ 949,867	$ 299	0	939,038	0	0	10,530
Common stock dividends paid (in dollars per share)	$ 0.935
Common Stock Dividends	$ (387,037)	0	0	(387,037)	0	0	0
Other, net	8,652	$ 0	$ 0	8,652	0	0	0
Shares, issued, ending balance at Jun. 30, 2020		474,916,234	20,000
Total equity, ending balance at Jun. 30, 2020	6,240,652	$ 4,749	$ 0	7,549,831	(524,903)	(7,536)	(781,489)
Net income	312,316	0	0	0	0	312,316	0
Other comprehensive loss	$ (5,715)	0	0	0	(5,715)	0	0
Preferred stock, dividends paid (in dollars per share)	$ 13.75
Preferred stock dividends	$ (275)	$ 0	0	0	0	(275)	0
Common Stock Issued During Period, Shares, Other		0
Common Stock Issued During Period, Value, Other	$ 5,789	$ 0	0	803	0	0	4,986
Common stock dividends paid (in dollars per share)	$ 0.935
Common Stock Dividends	$ (415,453)	0	0	(110,948)	0	(304,505)	0
Other, net	8,798	$ 0	$ 0	8,798	0	0	0
Shares, issued, ending balance at Sep. 30, 2020		474,916,234	20,000
Total equity, ending balance at Sep. 30, 2020	$ 6,146,112	$ 4,749	$ 0	$ 7,448,484	$ (530,618)	$ 0	$ (776,503)

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY CONSOLIDATED STATEMENT OF CHANGES IN EQUITY Parenthetical - $ / shares	3 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019
Statement of Stockholders' Equity [Abstract]
Preferred stock, dividends paid (in dollars per share)	$ 13.75	$ 13.75	$ 13.75	$ 13.75	$ 13.75	$ 13.75
Common stock dividends paid (in dollars per share)	$ 0.935	$ 0.935	$ 0.935	$ 0.89	$ 0.865	$ 0.86

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Notes)

9 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

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 2019 year-end Consolidated Balance Sheet data was derived from our audited Consolidated Financial Statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior year Consolidated 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.

In March 2020, the CARES Act was signed into law in response to the COVID-19 pandemic, and we opted into the CARES Act payroll tax deferral program, which will modestly benefit us, and the 401(k) penalty-free hardship withdrawal and loan deferral programs for employees.

Goodwill Impairment Review - We assess our goodwill for impairment at least annually as of July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. At July 1, 2020, we assessed qualitative factors subsequent to our first quarter 2020 impairment charges discussed below, to determine whether it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were less than their carrying amount. After assessing qualitative factors (including macroeconomic conditions, industry and market considerations, cost factors and overall financial performance), we determined that it was more likely than not that the fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units were not less than their respective carrying value, no further testing was necessary and goodwill was not considered impaired. At July 1, 2020, there was no remaining goodwill associated with our Natural Gas Gathering and Processing reporting unit.

Impairment Charges - Late in the first quarter 2020, we experienced a significant decline in our share price and market capitalization as the energy industry experienced historic events that led to a simultaneous demand and supply disruption. The World Health Organization declared COVID-19 a global pandemic and recommended containment and mitigation measures worldwide, which contributed to a massive economic slowdown and decreased demand for crude oil. In addition, Saudi Arabia and Russia increased production of crude oil as the two countries competed for market share. As a result, the global supply of crude oil significantly exceeded demand and led to a collapse in crude oil prices. Based on these events, we performed a Step 1 analysis in the first quarter 2020 to test our goodwill for impairment and evaluated certain long-lived asset groups and equity investments for impairment.

Goodwill - In the Step 1 analysis, an assessment is made by comparing the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying value of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. In January 2020, we adopted ASU 2017-04 in which the requirement to calculate the implied fair value of goodwill under the two-step impairment test was eliminated.

To estimate the fair value of our reporting units, we use two generally accepted valuation approaches, an income approach and a market approach, using assumptions consistent with a market participant’s perspective. Under the income approach, we use anticipated cash flows over a period of years plus a terminal value and discount these amounts to their present value using appropriate discount rates. Under the market approach, we apply EBITDA multiples to forecasted EBITDA. The multiples used are consistent with historical asset transactions. The forecasted cash flows are based on average forecasted cash flows for a reporting unit over a period of years.

Based on the results of our impairment test, we concluded that the carrying value of the Natural Gas Gathering and Processing reporting unit exceeded its estimated fair value, resulting in a noncash impairment charge of $153.4 million, which is included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020. The estimated fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units substantially exceeded their respective carrying values.

The following table sets forth our goodwill, by segment, for the periods indicated:

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Natural Gas Gathering and Processing	$	—	$	153,404
Natural Gas Liquids	371,217		371,217
Natural Gas Pipelines	156,375		156,375
Total goodwill	$	527,592	$	680,996

Long-lived assets - We assess our long-lived assets for impairment whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable. An impairment is indicated if the carrying amount of a long-lived asset exceeds the sum of the undiscounted future cash flows expected to result from the use and eventual disposition of the asset. If an impairment is indicated, we record an impairment loss equal to the difference between the carrying value and the fair value of the long-lived asset.

In the first quarter 2020, we evaluated our Natural Gas Gathering and Processing segment asset groups and determined that the carrying value of certain long-lived asset groups in western Oklahoma, Kansas and the Powder River Basin, where lower pricing impacted drilling and production levels, were not recoverable and exceeded their estimated fair value. We recorded noncash impairment charges of $380.5 million, which includes impairment to intangible assets of $19.9 million related to supply contracts. In our Natural Gas Liquids segment, we recorded noncash impairment charges of $70.2 million related to certain inactive assets, as our expectation for future use of the assets changed. These charges are included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020.

Investments in unconsolidated affiliates - The impairment test for equity-method investments considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary. Therefore, we periodically evaluate the amount at which we carry our equity-method investments to determine whether current events or circumstances warrant adjustments to our carrying values.

In the first quarter 2020, we evaluated our investments in unconsolidated affiliates and concluded that the carrying value of our 10.2% investment in Venice Energy Services Company in our Natural Gas Gathering and Processing segment exceeded its estimated fair value, resulting in a noncash impairment charge of $30.5 million, which includes an impairment to our equity-method goodwill of $22.3 million. We also concluded that the carrying value of our 50% investment in Chisholm Pipeline Company in our Natural Gas Liquids segment exceeded its estimated fair value, resulting in a noncash impairment charge of $7.2 million. These impairment charges are included within impairment of equity investments in our Consolidated Statement of Income for the nine months ended September 30, 2020.

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 or in our Annual Report were assessed and determined to be either not applicable or clarifications of ASUs previously issued or listed below. Except as discussed below or in our Annual Report, there have been no new accounting pronouncements that have become effective or have been issued that are of significance or potential significance to us. The following table provides a brief description of recently adopted 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
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	The impact of adopting this standard was not material.
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 adopted and implemented this standard prior to recording noncash impairment charges related to our goodwill, as described above.
ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting”	The standard provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met.	First quarter 2020	The impact of adopting this standard was not material.

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FAIR VALUE MEASUREMENTS (Notes)

9 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

Determining Fair Value - For our fair value measurements, we utilize market prices, third-party pricing services, present value methods and standard option valuation models to determine the price we would receive from the sale of an asset or the transfer of a liability in an orderly transaction at the measurement date. 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.

Many of the contracts in our derivative portfolio are executed in liquid markets where price transparency exists. Our financial commodity derivatives are generally settled through a NYMEX or Intercontinental Exchange (ICE) clearing broker account with daily margin requirements. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

We compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from the implied forward LIBOR yield curve. The fair value of our forward-starting interest-rate swaps is determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest-rate swap settlements. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using counterparty-specific bond yields. Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ materially from our estimates.

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. These balances are composed predominantly of exchange-traded derivative contracts for natural gas and crude oil.

•Level 2 - fair value measurements are based on significant observable pricing inputs, including quoted prices for similar assets and liabilities in active markets and inputs from third-party pricing services supported with corroborative evidence. These balances are composed of over-the-counter interest-rate derivatives.

•Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including internally developed commodity price curves that incorporate market data from broker quotes and third-party pricing services. These balances are composed predominantly of exchange-cleared and over-the-counter derivatives to hedge NGL price risk and natural gas basis risk between various transaction locations and the NYMEX Henry Hub. Our commodity derivatives are generally valued using forward quotes provided by third-party pricing services that are validated with other market data. We believe any measurement uncertainty at September 30, 2020, is immaterial as our Level 3 fair value measurements are based on unadjusted pricing information from broker quotes and third-party pricing services. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as our derivatives are primarily accounted for as hedges.

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, 2020
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Total derivative assets	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Derivative liabilities
Commodity contracts
Financial contracts	$	(13,509)	$	—	$	(47,240)	$	(60,749)	$	60,749	$	—
Interest-rate contracts	—		(231,991)		—		(231,991)		—		(231,991)
Total derivative liabilities	$	(13,509)	$	(231,991)	$	(47,240)	$	(292,740)	$	60,749	$	(231,991)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2020, we held no cash and posted $48.2 million of cash with various counterparties, including $13.9 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $34.3 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheet.

	December 31, 2019
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	10,892	$	—	$	55,557	$	66,449	$	(28,588)	$	37,861
Interest-rate contracts	—		581		—		581		—		581
Total derivative assets	$	10,892	$	581	$	55,557	$	67,030	$	(28,588)	$	38,442
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,811)	$	—	$	(24,785)	$	(29,596)	$	28,588	$	(1,008)
Interest-rate contracts	—		(201,941)		—		(201,941)		—		(201,941)
Total derivative liabilities	$	(4,811)	$	(201,941)	$	(24,785)	$	(231,537)	$	28,588	$	(202,949)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2019, we held no cash and posted $8.8 million of cash with various counterparties, which is included in other current assets in our Consolidated Balance Sheet.

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Derivative Assets (Liabilities)	2020		2019		2020		2019
	(Thousands of dollars)
Net assets at beginning of period	$	5,583	$	19,274	$	30,772	$	40,484
Total changes in fair value:
Settlements included in net income (a)	(6,194)		(12,380)		(29,471)		(38,044)
New Level 3 derivatives included in other comprehensive loss (b)	(2,033)		2,728		(5,140)		17,528
Unrealized change included in other comprehensive loss (b)	(2,700)		18,593		(1,505)		8,247
Net assets (liabilities) at end of period	$	(5,344)	$	28,215	$	(5,344)	$	28,215

(a) - Included in commodity sales revenues/cost of sales and fuel in our Consolidated Statements of Income.

(b) - Included in change in fair value of derivatives in our Consolidated Statements of Comprehensive Income.

During the three and nine months ended September 30, 2020 and 2019, there were no transfers in or out of Level 3 of the fair value hierarchy.

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 composed 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 $14.9 billion and $13.8 billion at September 30, 2020, and December 31, 2019, respectively. The book value of our consolidated long-term debt, including current maturities, was $14.3 billion and $12.5 billion at September 30, 2020, and December 31, 2019, respectively. The estimated fair value of the aggregate long-term debt 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.

Nonrecurring Fair Value Measurements - In the first quarter 2020, we incurred noncash impairment charges for certain long-lived assets and equity investments. The valuation of these assets and investments required the use of significant unobservable inputs. To estimate the fair value, we used two generally accepted valuation approaches, an income approach and a market approach. Under the income approach, our discounted cash flow analysis included the following inputs that are not readily available: a discount rate reflective of industry cost of capital, our estimated contract rates, volumes, operating and maintenance costs and capital expenditures. Under the market approach, our inputs included EBITDA multiples, which were estimated from recent peer acquisition transactions, and forecasted EBITDA, which incorporates inputs similar to those used under the income

approach. The estimated fair value of these assets is classified as Level 3. See Note A for additional information about our impairment charges.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Notes)

9 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

RISK-MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES

Risk-Management Activities - We are sensitive to changes in natural gas, crude oil and NGL prices, principally as a result of contractual terms under which these commodities are processed, purchased and sold. We are also subject to the risk of interest-rate fluctuation in the normal course of business. 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 our risk-management activities. We have not used these instruments for trading purposes.

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 may use the following commodity derivative instruments to reduce 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.

In our Natural Gas Gathering and Processing segment, we are exposed to commodity price risk as a result of retaining a portion of the commodity sales proceeds associated with our POP with fee contracts. Under certain POP with fee contracts, our fees and POP percentage may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. In certain commodity price environments, our contractual fees on these certain POP with fee contracts may decrease, which impacts the average fee rate in our Natural Gas Gathering and Processing segment. We also are exposed to basis risk between the various production and market locations where we buy and sell 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.

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

In our Natural Gas Pipelines segment, we are primarily exposed to commodity price risk on our intrastate pipelines because they consume natural gas in operations and retain natural gas from our customers for operations or as part of our fee for services provided. When the amount consumed in operations differs from the amount provided by our customers, our pipelines must buy or sell natural gas, or store or use natural gas inventory, which can expose this segment to commodity price risk depending on the regulatory treatment for this activity. To the extent that commodity price risk in our 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 natural gas price fluctuations. At September 30, 2020, and December 31, 2019, there were no financial derivative instruments with respect to our 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. In March 2020, we settled $750 million of our forward-starting interest-rate swaps related to our underwritten public offerings of

$1.75 billion senior unsecured notes resulting in a loss of $152.5 million, which is included in accumulated other comprehensive loss and will be amortized to interest expense over the term of the related debt. In May 2020, we settled the remaining $1.3 billion of our interest-rate swaps used to hedge our LIBOR-based interest payments resulting in a loss of $48.3 million, which was recognized into interest expense upon repayment of our $1.5 Billion Term Loan Agreement.

At September 30, 2020, and December 31, 2019, we had forward-starting interest-rate swaps with notional amounts totaling $1.1 billion and $1.8 billion, respectively, to hedge the variability of interest payments on a portion of our forecasted debt issuances. At December 31, 2019, we had interest-rate swaps with notional amounts totaling $1.3 billion to hedge the variability of our LIBOR-based interest payments, all of which have settled as of September 30, 2020. All of our 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 B for a discussion of the inputs associated with our fair value measurements. The following table sets forth the fair values of our derivative instruments presented on a gross basis for the periods indicated:

		September 30, 2020				December 31, 2019
	Location in our Consolidated Balance Sheets	Assets		(Liabilities)		Assets		(Liabilities)
Derivatives designated as hedging instruments		(Thousands of dollars)
Commodity contracts (a)
Financial contracts (b)	Other current assets	$	46,451	$	(60,373)	$	64,858	$	(26,997)
	Other deferred credits	—		—		1,591		(2,599)
Interest-rate contracts	Other current liabilities	—		—		—		(90,161)
	Other assets/other deferred credits	—		(231,991)		581		(111,780)
Total derivatives designated as hedging instruments		46,451		(292,364)		67,030		(231,537)
Derivatives not designated as hedging instruments
Commodity contracts (a)
Financial contracts (b)		408		(376)		—		—
Total derivatives not designated as hedging instruments		408		(376)		—		—
Total derivatives		$	46,859	$	(292,740)	$	67,030	$	(231,537)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us.

(b) - At September 30, 2020, our derivative net liability positions under master-netting arrangements for financial contracts were fully offset by $13.9 million of cash collateral.

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

		September 30, 2020				December 31, 2019
	Contract Type	Purchased/ Payor		Sold/ Receiver		Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
- Crude oil and NGLs (MMBbl)	Futures	15.3		(22.7)		7.9		(17.4)
Basis
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
Interest-rate contracts (Billions of dollars)	Swaps	$	1.1	$	—	$	3.1	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—
- Crude oil and NGLs (MMBbl)	Futures	0.2		(0.2)		—		—
Basis
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—

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

Cash Flow Hedges - The following table sets forth the unrealized change in fair value of cash flow hedges in other comprehensive loss for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Commodity contracts	$	(29,667)	$	32,169	$	18,472	$	43,877
Interest-rate contracts	9,213		(128,041)		(237,200)		(303,351)
Total unrealized change in fair value of cash flow hedges in other comprehensive loss	$	(20,454)	$	(95,872)	$	(218,728)	$	(259,474)

The following table sets forth the effect of cash flow hedges on net income for the periods indicated:

	Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income	Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2020		2019		2020		2019
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	2,167	$	38,234	$	100,304	$	85,375
	Cost of sales and fuel	(1,568)		(19,706)		(31,057)		(32,751)
Interest-rate contracts (a)	Interest expense	(8,998)		(6,903)		(83,817)		(14,222)
Total change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income on derivatives		$	(8,399)	$	11,625	$	(14,570)	$	38,402

(a) - The nine months ended September 30, 2020, includes a loss of $48.3 million on the settlement of our remaining $1.3 billion interest-rate swaps used to hedge our LIBOR-based interest payments.

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 use internally developed credit ratings for counterparties that do not have a credit rating.

Our financial commodity derivatives are generally settled through a NYMEX or Intercontinental Exchange (ICE) clearing broker account with daily margin requirements. However, we may enter into financial derivative instruments that contain provisions that require us to maintain an investment-grade credit rating from S&P and/or Moody’s. If our credit ratings on our 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, 2020.

The counterparties to our derivative contracts typically consist 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, 2020, the credit exposure from our derivative assets is with investment-grade companies in the financial services sector.

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DEBT DEBT (Notes)

9 Months Ended

Sep. 30, 2020

Debt Disclosure [Abstract]

Debt [Text Block]

DEBT

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

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Commercial paper outstanding, bearing a weighted-average interest rate of 2.16% as of December 31, 2019	$	—	$	220,000
Senior unsecured obligations:
$1,500,000 term loan at 2.7% as of December 31, 2019, due November 2021	—		1,250,000
$700,000 at 4.25% due February 2022	547,397		547,397
$900,000 at 3.375% due October 2022	900,000		900,000
$425,000 at 5.0% due September 2023	425,000		425,000
$500,000 at 7.5% due September 2023	500,000		500,000
$500,000 at 2.75% due September 2024	500,000		500,000
$500,000 at 4.9% due March 2025	500,000		500,000
$400,000 at 2.2% due September 2025	387,000		—
$600,000 at 5.85% due January 2026	600,000		—
$500,000 at 4.0% due July 2027	500,000		500,000
$800,000 at 4.55% due July 2028	800,000		800,000
$100,000 at 6.875% due September 2028	100,000		100,000
$700,000 at 4.35% due March 2029	700,000		700,000
$750,000 at 3.4% due September 2029	714,251		750,000
$850,000 at 3.1% due March 2030	780,093		—
$600,000 at 6.35% due January 2031	600,000		—
$400,000 at 6.0% due June 2035	400,000		400,000
$600,000 at 6.65% due October 2036	600,000		600,000
$600,000 at 6.85% due October 2037	600,000		600,000
$650,000 at 6.125% due February 2041	650,000		650,000
$400,000 at 6.2% due September 2043	400,000		400,000
$700,000 at 4.95% due July 2047	689,006		700,000
$1,000,000 at 5.2% due July 2048	1,000,000		1,000,000
$750,000 at 4.45% due September 2049	723,736		750,000
$500,000 at 4.5% due March 2050	453,585		—
$300,000 at 7.15% due January 2051	300,000		—
Guardian Pipeline
Weighted average 7.85% due December 2022	15,570		21,307
Total debt	14,385,638		12,813,704
Unamortized portion of terminated swaps	13,743		15,032
Unamortized debt issuance costs and discounts	(142,392)		(121,329)
Current maturities of long-term debt	(7,650)		(7,650)
Short-term borrowings (a)	—		(220,000)
Long-term debt	$	14,249,339	$	12,479,757

(a) - Individual issuances of commercial paper under our commercial paper program generally mature in 90 days or less.

$2.5 Billion Credit Agreement - Our $2.5 Billion Credit Agreement is a revolving credit facility and contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of net indebtedness to adjusted EBITDA (EBITDA, as defined in our $2.5 Billion 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 at September 30, 2020. In June 2020, we amended the $2.5 Billion Credit Agreement by, among other things, modifying the leverage ratio so that we may net up to $700 million of cash on hand against our consolidated indebtedness for purposes of calculating the ratio’s numerator for the fiscal quarters ending June 30, 2020, September 30, 2020, and December 31, 2020. At September 30, 2020, we had no outstanding borrowings, our ratio of net indebtedness to adjusted EBITDA was 4.6 to 1, and we were in compliance with all covenants under our $2.5 Billion Credit Agreement.

In October 2020, we acquired additional interests in one of our equity investments and a related asset for $27 million, which allowed us to elect an acquisition adjustment period under our $2.5 Billion Credit Agreement and, as a result, increased our leverage ratio covenant to 5.5 to 1 for the fourth quarter 2020 and the two following quarters.

Debt Issuances - In May 2020, we completed an underwritten public offering of $1.5 billion senior unsecured notes consisting of $600 million, 5.85% senior notes due 2026; $600 million, 6.35% senior notes due 2031; and $300 million, 7.15% senior notes due 2051. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.48 billion. A portion of the proceeds were used to repay the outstanding borrowings under our $1.5 Billion Term Loan Agreement. The remainder was used for general corporate purposes.

In March 2020, we completed an underwritten public offering of $1.75 billion senior unsecured notes consisting of $400 million, 2.2% senior notes due 2025; $850 million, 3.1% senior notes due 2030; and $500 million, 4.5% senior notes due 2050. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were $1.73 billion. A portion of the proceeds were used to pay all outstanding amounts under our commercial paper program. The remainder was used for general corporate purposes, which included repayment of other existing indebtedness and funding capital expenditures.

Debt Repayments - In May 2020, we repaid the remaining $1.25 billion of our $1.5 Billion Term Loan Agreement with cash on hand from our May 2020 public offering of $1.5 billion senior unsecured notes.

During the three and nine months ended September 30, 2020, we repurchased in the open market outstanding principal of certain of our senior notes in the amounts of $28.0 million and $202.3 million, respectively, for an aggregate repurchase price of $25.4 million and $177.7 million, respectively, with cash on hand. In connection with these open market repurchases, we recognized $2.2 million and $22.2 million of gains on extinguishment of debt, which is included in other income in our Consolidated Statement of Income for the three and nine months ended September 30, 2020, respectively.

Debt Guarantees - We, ONEOK Partners and the Intermediate Partnership have cross guarantees in place for our and ONEOK Partners’ indebtedness.

For additional discussion of our $2.5 Billion Credit Agreement, see Note F of the Notes to Consolidated Financial Statements in our Annual Report.

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EQUITY (Notes)

9 Months Ended

Sep. 30, 2020

Equity [Abstract]

EQUITY

EQUITY

Equity Issuances - In July 2020, we established an “at-the-market” equity program for the offer and sale from time to time of our common stock up to an aggregate offering price of $1.0 billion. The program allows us to offer and sell common stock at prices we deem appropriate through a sales agent, in forward sales transactions through a forward seller or directly to one or more of the program’s managers acting as principals. Sales of our common stock may be made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. No shares have been sold through our “at-the-market” program as of the date of this report.

In June 2020, we completed an underwritten public offering of 29.9 million shares of our common stock at a public offering price of $32.00 per share, generating net proceeds, after deducting underwriting discounts, commissions and offering expenses, of $937.0 million. A portion of the proceeds were, and we anticipate the remainder will be, used for general corporate purposes, including repayment of existing indebtedness and funding capital expenditures.

Dividends - Holders of our common stock share equally in any dividend declared by our Board of Directors, subject to the rights of the holders of outstanding preferred stock. Dividends paid on our common stock in February 2020, May 2020 and August 2020 were $0.935 per share. A dividend of $0.935 per share was declared for shareholders of record at the close of business on November 2, 2020, payable November 13, 2020.

Our Series E Preferred Stock pays 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% per year. We paid dividends for the Series E Preferred Stock of $0.3 million in February 2020, May 2020 and August 2020. Dividends totaling $0.3 million were declared for the Series E Preferred Stock and are payable November 13, 2020.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Notes)

9 Months Ended

Sep. 30, 2020

ACCUMULATED OTHER COMPREHENSIVE LOSS

ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Risk- Management Assets/Liabilities (a)		Retirement and Other Postretirement Benefit Plan Obligations (a) (b)		Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)		Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2020	$	(233,520)	$	(131,481)	$	(8,999)	$	(374,000)
Other comprehensive income (loss) before reclassifications	(168,421)		59		(10,893)		(179,255)
Amounts reclassified to net income (c)	11,210		10,626		801		22,637
Other comprehensive income (loss)	(157,211)		10,685		(10,092)		(156,618)
September 30, 2020	$	(390,731)	$	(120,796)	$	(19,091)	$	(530,618)

(a) - All amounts are presented net of tax.

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

(c) - See Note C for details of amounts reclassified to net income for risk-management assets/liabilities and Note H for retirement and other postretirement benefit plan obligations.

The following table sets forth information about the balance of accumulated other comprehensive loss at September 30, 2020, representing unrealized gains (losses) related to risk-management assets and liabilities:

	Risk- Management Assets/Liabilities (a)
	(Thousands of dollars)
Commodity derivative instruments expected to be realized within the next 15 months (b)	$	(10,988)
Settled interest-rate swaps to be recognized over the life of the long-term, fixed-rate debt (c)	(201,110)
Interest-rate swaps with future settlement dates expected to be amortized over the life of long-term debt	(178,633)
Accumulated other comprehensive loss at September 30, 2020	$	(390,731)

(a) - All amounts are presented net of tax.

(b) - Based on September 30, 2020, commodity prices, we expect $8.4 million in net losses, net of tax, over the next 12 months and $2.6 million in net losses, net of tax, thereafter.

(c) - We expect net losses of $30.3 million, net of tax, will be reclassified into earnings during the next 12 months.

The remaining amounts in accumulated other comprehensive loss relate primarily to our retirement and other postretirement benefit plan obligations, which are expected to be amortized over the average remaining service period of employees participating in these plans.

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EARNINGS PER SHARE EARNINGS PER SHARE (Notes)

9 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

EARNINGS PER SHARE

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

	Three Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	312,041	445,103	$	0.70
Diluted EPS
Effect of dilutive securities	—		407
Net income available for common stock and common stock equivalents	$	312,041	445,510	$	0.70

	Three Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	308,880	413,816	$	0.75
Diluted EPS
Effect of dilutive securities	—		1,762
Net income available for common stock and common stock equivalents	$	308,880	415,578	$	0.74

	Nine Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	303,955	426,369	$	0.71
Diluted EPS
Effect of dilutive securities	—		628
Net income available for common stock and common stock equivalents	$	303,955	426,997	$	0.71

	Nine Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	957,501	413,443	$	2.32
Diluted EPS
Effect of dilutive securities	—		1,834
Net income available for common stock and common stock equivalents	$	957,501	415,277	$	2.31

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EMPLOYEE BENEFIT PLANS EMPLOYEE BENEFIT PLANS (Notes)

9 Months Ended

Sep. 30, 2020

Defined Benefit Plan [Abstract]

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS

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

	Retirement Benefits				Other Postretirement Benefits
	Three Months Ended				Three Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	2,036	$	1,954	$	115	$	117
Interest cost	4,574		5,126		442		509
Expected return on plan assets	(6,232)		(5,892)		(722)		(570)
Amortization of prior service cost (credit) (a)	28		—		—		(57)
Amortization of net loss (a)	4,571		3,158		1		74
Net periodic benefit cost (income)	$	4,977	$	4,346	$	(164)	$	73

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $1.1 million and $0.7 million reclassified to income tax expense for the three months ended September 30, 2020 and 2019, respectively.

	Retirement Benefits				Other Postretirement Benefits
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	6,108	$	5,862	$	345	$	351
Interest cost	13,722		15,378		1,326		1,527
Expected return on plan assets	(18,696)		(17,676)		(2,166)		(1,710)
Amortization of prior service cost (credit) (a)	84		—		—		(171)
Amortization of net loss (a)	13,713		9,474		3		222
Net periodic benefit cost (income)	$	14,931	$	13,038	$	(492)	$	219

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $3.2 million and $2.2 million reclassified to income tax expense for the nine months ended September 30, 2020 and 2019, respectively.

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UNCONSOLIDATED AFFILIATES (Notes)

9 Months Ended

Sep. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

UNCONSOLIDATED AFFILIATES

UNCONSOLIDATED AFFILIATES

Equity in Net Earnings from Investments and Impairments - The following table sets forth our equity in net earnings (loss) from investments for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Northern Border Pipeline	$	22,037	$	16,102	$	57,028	$	50,593
Overland Pass Pipeline	8,007		15,481		30,090		48,340
Roadrunner	8,033		7,421		21,275		19,836
Other	(31)		(1,428)		(392)		(3,594)
Equity in net earnings from investments	$	38,046	$	37,576	$	108,001	$	115,175
Impairment of equity investments	$	—	$	—	$	(37,730)	$	—

In the first quarter 2020, we incurred a noncash impairment charge of $30.5 million related to our 10.2% investment in Venice Energy Services Company in our Natural Gas Gathering and Processing segment, which includes $22.3 million related to equity-method goodwill, and a $7.2 million noncash impairment charge related to our 50% investment in Chisholm Pipeline Company in our Natural Gas Liquids segment. Our remaining equity-method goodwill was $16.5 million at September 30, 2020. For additional information on our impairment charges, see Note A.

We incurred expenses in transactions with unconsolidated affiliates of $35.8 million and $41.9 million for the three months ended September 30, 2020 and 2019, respectively, and $108.4 million and $124.2 million for the nine months ended September 30, 2020 and 2019, respectively, primarily related to Overland Pass Pipeline and Northern Border Pipeline. Accounts payable to our equity-method investees at September 30, 2020, and December 31, 2019, were $13.3 million and $13.5 million, respectively.

We have an operating agreement with Roadrunner that provides for reimbursement or payment to us for management services and certain operating costs. Reimbursements and payments from Roadrunner included in operating income in our Consolidated Statements of Income for the three and nine months ended September 30, 2020 and 2019, were not material.

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COMMITMENTS AND CONTINGENCIES (Notes)

9 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIESEnvironmental Matters and Pipeline Safety - The operation of pipelines, plants and other facilities for the gathering, processing, fractionation, 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, we must comply with laws and regulations that relate to air and water quality, hazardous and solid waste management and disposal, cultural resource protection and other environmental and safety matters. The cost of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with these laws, 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 or construction.

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

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LEASES (Notes)

9 Months Ended

Sep. 30, 2020

Leases [Abstract]

Leases of Lessee Disclosure [Text Block]

LEASES

In December 2019, we entered into an operating lease for pipeline capacity with a lease term of 10 years that commenced January 1, 2020. In connection with this lease, we recognized an operating lease right-of-use asset and a lease liability with remaining balances of $70.7 million and $71.4 million, respectively, as of September 30, 2020. During the nine months ended September 30, 2020, we entered into certain operating leases and recognized operating lease right-of-use assets and lease liabilities with remaining balances of $16.2 million at the end of the period. At September 30, 2020, the weighted-average remaining lease term and the weighted-average discount rate for our operating leases were 8.5 years and 3.19%, respectively.

The following table sets forth supplemental cash flow information related to our leases:

	Nine Months Ended
	September 30,
	2020		2019
	(Thousands of dollars)
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	9,662	$	4,972
Financing cash flows for finance lease	$	1,443	$	1,307
Right-of-use assets obtained in exchange for operating lease liabilities (noncash)	$	99,197	$	3,663

The following table sets forth the maturity of our lease liabilities as of September 30, 2020:

	Finance Lease		Operating Leases
	(Millions of dollars)
Remainder of 2020	$	1.2	$	4.1
2021	4.5		16.4
2022	4.5		15.1
2023	4.5		13.8
2024	4.5		12.5
2025 and beyond	17.1		58.2
Total lease payments	36.3		120.1
Less: Interest	11.5		15.6
Present value of lease liabilities	$	24.8	$	104.5

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REVENUE REVENUE (Notes)

9 Months Ended

Sep. 30, 2020

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

REVENUES

Accounting Policies - Our revenue recognition policy is described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

Contract Assets and Contract Liabilities - Our contract asset balances at the beginning and end of the period primarily relate to our firm service transportation contracts with tiered rates, which are not material. The following table sets forth the balances in contract liabilities for the periods indicated:

Contract Liabilities	(Millions of dollars)
Balance at December 31, 2019 (a)	$	57.1
Revenue recognized included in beginning balance (b)	(35.1)
Net additions	24.3
Balance at September 30, 2020 (c)	$	46.3

(a) - Contract liabilities of $22.2 million and $34.9 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

(b) - Includes a contract settlement in the second quarter 2020 of revenue previously deferred.

(c) - Contract liabilities of $27.6 million and $18.7 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

Receivables from Customers and Revenue Disaggregation - Substantially all of the balances in accounts receivable on our Consolidated Balance Sheets at September 30, 2020, and December 31, 2019, relate to customer receivables. Revenues sources are disaggregated in Note M.

Transaction Price Allocated to Unsatisfied Performance Obligations - We do not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) variable consideration on contracts for which we recognize revenue at the amount to which we have the right to invoice for services performed.

The following table presents aggregate value allocated to unsatisfied performance obligations as of September 30, 2020, and the amounts we expect to recognize in revenue in future periods, related primarily to firm transportation and storage contracts with remaining contract terms ranging from one month to 24 years:

Expected Period of Recognition in Revenue	(Millions of dollars)
Remainder of 2020	$	87.1
2021	320.0
2022	259.9
2023	230.9
2024 and beyond	901.0
Total estimated transaction price allocated to unsatisfied performance obligations	$	1,798.9

The table above excludes variable consideration allocated entirely to wholly unsatisfied performance obligations, wholly unsatisfied promises to transfer distinct goods or services that are part of a single performance obligation and consideration we determine to be fully constrained. The amounts we determined to be fully constrained relate to future sales obligations under long-term sales contracts where the transaction price is not known and minimum volume agreements, which we consider to be fully constrained until invoiced.

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SEGMENTS (Notes)

9 Months Ended

Sep. 30, 2020

Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]

SEGMENTS

SEGMENTS

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

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

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

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

Other and eliminations consist of corporate costs, the operating and leasing activities of our headquarters building and related parking facility and eliminations necessary 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.

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, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	239,810	$	1,658,123	$	—	$	1,897,933
Residue natural gas sales	178,492		—		3,998		182,490
Gathering, processing and exchange services revenue	36,459		132,210		—		168,669
Transportation and storage revenue	—		39,774		113,047		152,821
Other	4,644		2,110		251		7,005
Total revenues (c)	459,405		1,832,217		117,296		2,408,918
Cost of sales and fuel (exclusive of depreciation and operating costs)	(207,519)		(1,289,667)		(3,389)		(1,500,575)
Operating costs	(69,351)		(101,223)		(34,567)		(205,141)
Equity in net earnings (loss) from investments	(42)		8,018		30,070		38,046
Noncash compensation expense and other	655		1,898		427		2,980
Segment adjusted EBITDA	$	183,148	$	451,243	$	109,837	$	744,228
Depreciation and amortization	$	(66,459)	$	(71,534)	$	(14,243)	$	(152,236)
Capital expenditures	$	63,030	$	298,891	$	12,978	$	374,899

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $541.7 million, of which $495.4 million related to revenues within the segment, and cost of sales and fuel of $137.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $71.8 million and cost of sales and fuel of $9.6 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $235.6 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,897,933	$	(224,731)	$	1,673,202
Residue natural gas sales	182,490		(5,897)		176,593
Gathering, processing and exchange services revenue	168,669		—		168,669
Transportation and storage revenue	152,821		(3,597)		149,224
Other	7,005		(429)		6,576
Total revenues (a)	$	2,408,918	$	(234,654)	$	2,174,264
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,500,575)	$	234,901	$	(1,265,674)
Operating costs	$	(205,141)	$	212	$	(204,929)
Depreciation and amortization	$	(152,236)	$	(1,009)	$	(153,245)
Equity in net earnings from investments	$	38,046	$	—	$	38,046
Capital expenditures	$	374,899	$	5,143	$	380,042

(a) - Noncustomer revenue for the three months ended September 30, 2020, totaled $4.0 million related primarily to gains from derivatives on commodity contracts.

Three Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	244,932	$	1,746,630	$	—	$	1,991,562
Residue natural gas sales	185,303		—		231		185,534
Gathering, processing and exchange services revenue	42,795		105,179		—		147,974
Transportation and storage revenue	—		46,407		119,924		166,331
Other	3,182		2,291		1,393		6,866
Total revenues (c)	476,212		1,900,507		121,548		2,498,267
Cost of sales and fuel (exclusive of depreciation and operating costs)	(210,739)		(1,438,206)		(381)		(1,649,326)
Operating costs	(91,227)		(114,903)		(40,170)		(246,300)
Equity in net earnings (loss) from investments	(1,837)		15,890		23,523		37,576
Noncash compensation expense and other	2,883		4,174		(701)		6,356
Segment adjusted EBITDA	$	175,292	$	367,462	$	103,819	$	646,573
Depreciation and amortization	$	(55,781)	$	(50,419)	$	(14,330)	$	(120,530)
Capital expenditures	$	245,745	$	738,038	$	27,767	$	1,011,550

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $379.7 million, of which $315.7 million related to revenues within the segment, and cost of sales and fuel of $129.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $72.3 million and cost of sales and fuel of $5.1 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $244.2 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,991,562	$	(230,080)	$	1,761,482
Residue natural gas sales	185,534		(567)		184,967
Gathering, processing and exchange services revenue	147,974		—		147,974
Transportation and storage revenue	166,331		(4,010)		162,321
Other	6,866		(382)		6,484
Total revenues (a)	$	2,498,267	$	(235,039)	$	2,263,228
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,649,326)	$	234,798	$	(1,414,528)
Operating costs	$	(246,300)	$	1,165	$	(245,135)
Depreciation and amortization	$	(120,530)	$	(900)	$	(121,430)
Equity in net earnings from investments	$	37,576	$	—	$	37,576
Capital expenditures	$	1,011,550	$	7,624	$	1,019,174

(a) - Noncustomer revenue for the three months ended September 30, 2019, totaled $89.0 million related primarily to gains from derivatives on commodity contracts.

Nine Months Ended September 30, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	569,308	$	4,429,414	$	—	$	4,998,722
Residue natural gas sales	518,435		—		6,033		524,468
Gathering, processing and exchange services revenue	110,345		370,920		—		481,265
Transportation and storage revenue	—		131,410		353,188		484,598
Other	11,106		6,779		916		18,801
Total revenues (c)	1,209,194		4,938,523		360,137		6,507,854
Cost of sales and fuel (exclusive of depreciation and operating costs)	(541,910)		(3,473,575)		(5,096)		(4,020,581)
Operating costs	(232,489)		(297,771)		(100,966)		(631,226)
Equity in net earnings (loss) from investments	(1,385)		31,083		78,303		108,001
Noncash compensation expense and other	(1,865)		1,541		(184)		(508)
Segment adjusted EBITDA	$	431,545	$	1,199,801	$	332,194	$	1,963,540
Depreciation and amortization	$	(180,634)	$	(198,440)	$	(43,937)	$	(423,011)
Impairment charges	$	(564,353)	$	(77,401)	$	—	$	(641,754)
Investments in unconsolidated affiliates	$	2,276	$	426,621	$	361,476	$	790,373
Total assets	$	6,437,301	$	13,449,529	$	2,082,846	$	21,969,676
Capital expenditures	$	362,811	$	1,504,881	$	40,478	$	1,908,170

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1,454.0 million, of which $1,306.2 million related to revenues within the segment, and cost of sales and fuel of $375.0 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $225.6 million and cost of sales and fuel of $22.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $557.1 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	4,998,722	$	(513,170)	$	4,485,552
Residue natural gas sales	524,468		(10,860)		513,608
Gathering, processing and exchange services revenue	481,265		—		481,265
Transportation and storage revenue	484,598		(11,033)		473,565
Other	18,801		(1,126)		17,675
Total revenues (a)	$	6,507,854	$	(536,189)	$	5,971,665
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(4,020,581)	$	537,521	$	(3,483,060)
Operating costs	$	(631,226)	$	(5,207)	$	(636,433)
Depreciation and amortization	$	(423,011)	$	(3,003)	$	(426,014)
Impairment charges	$	(641,754)	$	—	$	(641,754)
Equity in net earnings from investments	$	108,001	$	—	$	108,001
Investments in unconsolidated affiliates	$	790,373	$	—	$	790,373
Total assets	$	21,969,676	$	811,200	$	22,780,876
Capital expenditures	$	1,908,170	$	15,833	$	1,924,003

(a) - Noncustomer revenue for the nine months ended September 30, 2020, totaled $103.0 million related primarily to gains from derivatives on commodity contracts.

Nine Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	890,021	$	5,826,297	$	—	$	6,716,318
Residue natural gas sales	725,672		—		1,242		726,914
Gathering, processing and exchange services revenue	126,073		309,571		—		435,644
Transportation and storage revenue	—		141,384		350,029		491,413
Other	11,287		7,313		4,208		22,808
Total revenues (c)	1,753,053		6,284,565		355,479		8,393,097
Cost of sales and fuel (exclusive of depreciation and operating costs)	(971,397)		(4,914,452)		(3,785)		(5,889,634)
Operating costs	(271,236)		(340,274)		(113,043)		(724,553)
Equity in net earnings (loss) from investments	(4,660)		49,406		70,429		115,175
Noncash compensation expense and other	8,399		12,618		1,931		22,948
Segment adjusted EBITDA	$	514,159	$	1,091,863	$	311,011	$	1,917,033
Depreciation and amortization	$	(162,014)	$	(143,166)	$	(42,653)	$	(347,833)
Investments in unconsolidated affiliates	$	35,252	$	445,755	$	389,504	$	870,511
Total assets	$	6,546,417	$	11,662,489	$	2,083,773	$	20,292,679
Capital expenditures	$	674,115	$	1,969,138	$	77,861	$	2,721,114

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1.0 billion, of which $853.0 million related to revenues within the segment, and cost of sales and fuel of $364.9 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $214.7 million and cost of sales and fuel of $14.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $897.9 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	6,716,318	$	(878,958)	$	5,837,360
Residue natural gas sales	726,914		(567)		726,347
Gathering, processing and exchange services revenue	435,644		—		435,644
Transportation and storage revenue	491,413		(11,827)		479,586
Other	22,808		(984)		21,824
Total revenues (a)	$	8,393,097	$	(892,336)	$	7,500,761
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(5,889,634)	$	892,935	$	(4,996,699)
Operating costs	$	(724,553)	$	964	$	(723,589)
Depreciation and amortization	$	(347,833)	$	(2,719)	$	(350,552)
Equity in net earnings from investments	$	115,175	$	—	$	115,175
Investments in unconsolidated affiliates	$	870,511	$	—	$	870,511
Total assets	$	20,292,679	$	1,043,228	$	21,335,907
Capital expenditures	$	2,721,114	$	18,224	$	2,739,338

(a) - Noncustomer revenue for the nine months ended September 30, 2019, totaled $129.9 million related primarily to gains from derivatives on commodity contracts.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Reconciliation of net income to total segment adjusted EBITDA
Net income	$	312,316	$	309,155	$	304,780	$	958,326
Add:
Interest expense, net of capitalized interest	176,371		129,577		535,955		362,490
Depreciation and amortization	153,245		121,430		426,014		350,552
Income tax expense	106,555		97,365		94,300		274,234
Impairment charges	—		—		641,754		—
Noncash compensation expense	1,606		9,757		1,261		20,412
Other corporate costs and equity AFUDC (a)	(5,865)		(20,711)		(40,524)		(48,981)
Total segment adjusted EBITDA	$	744,228	$	646,573	$	1,963,540	$	1,917,033

(a) - The three and nine months ended September 30, 2020, include corporate gains of $2.2 million and $22.2 million, respectively, on extinguishment of debt related to open market repurchases.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Sep. 30, 2020

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

Impairment or Disposal of Long-Lived Assets, Including Intangible Assets, Policy [Policy Text Block]

Impairment Charges - Late in the first quarter 2020, we experienced a significant decline in our share price and market capitalization as the energy industry experienced historic events that led to a simultaneous demand and supply disruption. The World Health Organization declared COVID-19 a global pandemic and recommended containment and mitigation measures worldwide, which contributed to a massive economic slowdown and decreased demand for crude oil. In addition, Saudi Arabia and Russia increased production of crude oil as the two countries competed for market share. As a result, the global supply of crude oil significantly exceeded demand and led to a collapse in crude oil prices. Based on these events, we performed a Step 1 analysis in the first quarter 2020 to test our goodwill for impairment and evaluated certain long-lived asset groups and equity investments for impairment.

Goodwill - In the Step 1 analysis, an assessment is made by comparing the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying value of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. In January 2020, we adopted ASU 2017-04 in which the requirement to calculate the implied fair value of goodwill under the two-step impairment test was eliminated.

To estimate the fair value of our reporting units, we use two generally accepted valuation approaches, an income approach and a market approach, using assumptions consistent with a market participant’s perspective. Under the income approach, we use anticipated cash flows over a period of years plus a terminal value and discount these amounts to their present value using appropriate discount rates. Under the market approach, we apply EBITDA multiples to forecasted EBITDA. The multiples used are consistent with historical asset transactions. The forecasted cash flows are based on average forecasted cash flows for a reporting unit over a period of years.

Based on the results of our impairment test, we concluded that the carrying value of the Natural Gas Gathering and Processing reporting unit exceeded its estimated fair value, resulting in a noncash impairment charge of $153.4 million, which is included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020. The estimated fair value of our Natural Gas Liquids and Natural Gas Pipelines reporting units substantially exceeded their respective carrying values.

The following table sets forth our goodwill, by segment, for the periods indicated:

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Natural Gas Gathering and Processing	$	—	$	153,404
Natural Gas Liquids	371,217		371,217
Natural Gas Pipelines	156,375		156,375
Total goodwill	$	527,592	$	680,996

Long-lived assets - We assess our long-lived assets for impairment whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable. An impairment is indicated if the carrying amount of a long-lived asset exceeds the sum of the undiscounted future cash flows expected to result from the use and eventual disposition of the asset. If an impairment is indicated, we record an impairment loss equal to the difference between the carrying value and the fair value of the long-lived asset.

In the first quarter 2020, we evaluated our Natural Gas Gathering and Processing segment asset groups and determined that the carrying value of certain long-lived asset groups in western Oklahoma, Kansas and the Powder River Basin, where lower pricing impacted drilling and production levels, were not recoverable and exceeded their estimated fair value. We recorded noncash impairment charges of $380.5 million, which includes impairment to intangible assets of $19.9 million related to supply contracts. In our Natural Gas Liquids segment, we recorded noncash impairment charges of $70.2 million related to certain inactive assets, as our expectation for future use of the assets changed. These charges are included within impairment charges in our Consolidated Statement of Income for the nine months ended September 30, 2020.

Investments in unconsolidated affiliates - The impairment test for equity-method investments considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary. Therefore, we periodically evaluate the amount at which we carry our equity-method investments to determine whether current events or circumstances warrant adjustments to our carrying values.

In the first quarter 2020, we evaluated our investments in unconsolidated affiliates and concluded that the carrying value of our 10.2% investment in Venice Energy Services Company in our Natural Gas Gathering and Processing segment exceeded its estimated fair value, resulting in a noncash impairment charge of $30.5 million, which includes an impairment to our equity-method goodwill of $22.3 million. We also concluded that the carrying value of our 50% investment in Chisholm Pipeline Company in our Natural Gas Liquids segment exceeded its estimated fair value, resulting in a noncash impairment charge of $7.2 million. These impairment charges are included within impairment of equity investments in our Consolidated Statement of Income for the nine months ended September 30, 2020.

Basis of Accounting, Policy [Policy Text Block]

Our accompanying unaudited Consolidated Financial Statements have been prepared pursuant to the rules and regulations of the SEC. These statements have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2019 year-end Consolidated Balance Sheet data was derived from our audited Consolidated Financial Statements but does not include all disclosures required by GAAP. Certain reclassifications have been made in the prior year Consolidated 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.

New Accounting Pronouncements, Policy [Policy Text Block]

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 or in our Annual Report were assessed and determined to be either not applicable or clarifications of ASUs previously issued or listed below. Except as discussed below or in our Annual Report, there have been no new accounting pronouncements that have become effective or have been issued that are of significance or potential significance to us. The following table provides a brief description of recently adopted 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
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	The impact of adopting this standard was not material.
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 adopted and implemented this standard prior to recording noncash impairment charges related to our goodwill, as described above.
ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting”	The standard provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met.	First quarter 2020	The impact of adopting this standard was not material.

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FAIR VALUE MEASUREMENTS FAIR VALUE MEASUREMENTS (Policies)

9 Months Ended

Sep. 30, 2020

Fair Value Accounting Policy [Abstract]

Fair Value of Financial Instruments, Policy [Policy Text Block]

Determining Fair Value - For our fair value measurements, we utilize market prices, third-party pricing services, present value methods and standard option valuation models to determine the price we would receive from the sale of an asset or the transfer of a liability in an orderly transaction at the measurement date. 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.

Many of the contracts in our derivative portfolio are executed in liquid markets where price transparency exists. Our financial commodity derivatives are generally settled through a NYMEX or Intercontinental Exchange (ICE) clearing broker account with daily margin requirements. We validate our valuation inputs with third-party information and settlement prices from other sources, where available.

We compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from the implied forward LIBOR yield curve. The fair value of our forward-starting interest-rate swaps is determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest-rate swap settlements. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using counterparty-specific bond yields. Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ materially from our estimates.

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. These balances are composed predominantly of exchange-traded derivative contracts for natural gas and crude oil.

•Level 2 - fair value measurements are based on significant observable pricing inputs, including quoted prices for similar assets and liabilities in active markets and inputs from third-party pricing services supported with corroborative evidence. These balances are composed of over-the-counter interest-rate derivatives.

•Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including internally developed commodity price curves that incorporate market data from broker quotes and third-party pricing services. These balances are composed predominantly of exchange-cleared and over-the-counter derivatives to hedge NGL price risk and natural gas basis risk between various transaction locations and the NYMEX Henry Hub. Our commodity derivatives are generally valued using forward quotes provided by third-party pricing services that are validated with other market data. We believe any measurement uncertainty at September 30, 2020, is immaterial as our Level 3 fair value measurements are based on unadjusted pricing information from broker quotes and third-party pricing services. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as our derivatives are primarily accounted for as hedges.

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

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REVENUE REVENUE (Policies)	9 Months Ended
	Sep. 30, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Policy Text Block]	Accounting Policies - Our revenue recognition policy is described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

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SEGMENTS SEGMENTS (Policies)	9 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Segment Accounting Policy [Policy Text Block]	Accounting Policies - The accounting policies of the segments are described in Note A of the Notes to Consolidated Financial Statements in our Annual Report.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

9 Months Ended

Sep. 30, 2020

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill by Segment

The following table sets forth our goodwill, by segment, for the periods indicated:

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Natural Gas Gathering and Processing	$	—	$	153,404
Natural Gas Liquids	371,217		371,217
Natural Gas Pipelines	156,375		156,375
Total goodwill	$	527,592	$	680,996

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FAIR VALUE MEASUREMENTS (Tables)

9 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Recurring Fair Value Measurements

The following tables set forth our recurring fair value measurements for the periods indicated:

	September 30, 2020
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Total derivative assets	$	4,963	$	—	$	41,896	$	46,859	$	(46,859)	$	—
Derivative liabilities
Commodity contracts
Financial contracts	$	(13,509)	$	—	$	(47,240)	$	(60,749)	$	60,749	$	—
Interest-rate contracts	—		(231,991)		—		(231,991)		—		(231,991)
Total derivative liabilities	$	(13,509)	$	(231,991)	$	(47,240)	$	(292,740)	$	60,749	$	(231,991)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2020, we held no cash and posted $48.2 million of cash with various counterparties, including $13.9 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $34.3 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheet.

	December 31, 2019
	Level 1		Level 2		Level 3		Total - Gross		Netting (a)		Total - Net
	(Thousands of dollars)
Derivative assets
Commodity contracts
Financial contracts	$	10,892	$	—	$	55,557	$	66,449	$	(28,588)	$	37,861
Interest-rate contracts	—		581		—		581		—		581
Total derivative assets	$	10,892	$	581	$	55,557	$	67,030	$	(28,588)	$	38,442
Derivative liabilities
Commodity contracts
Financial contracts	$	(4,811)	$	—	$	(24,785)	$	(29,596)	$	28,588	$	(1,008)
Interest-rate contracts	—		(201,941)		—		(201,941)		—		(201,941)
Total derivative liabilities	$	(4,811)	$	(201,941)	$	(24,785)	$	(231,537)	$	28,588	$	(202,949)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheet 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, 2019, we held no cash and posted $8.8 million of cash with various counterparties, which is included in other current assets in our Consolidated Balance Sheet.

Reconciliation of Level 3 Fair Value Measurements

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

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
Derivative Assets (Liabilities)	2020		2019		2020		2019
	(Thousands of dollars)
Net assets at beginning of period	$	5,583	$	19,274	$	30,772	$	40,484
Total changes in fair value:
Settlements included in net income (a)	(6,194)		(12,380)		(29,471)		(38,044)
New Level 3 derivatives included in other comprehensive loss (b)	(2,033)		2,728		(5,140)		17,528
Unrealized change included in other comprehensive loss (b)	(2,700)		18,593		(1,505)		8,247
Net assets (liabilities) at end of period	$	(5,344)	$	28,215	$	(5,344)	$	28,215

(a) - Included in commodity sales revenues/cost of sales and fuel in our Consolidated Statements of Income.

(b) - Included in change in fair value of derivatives in our Consolidated Statements of Comprehensive Income.

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)

9 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivatives

The following table sets forth the fair values of our derivative instruments presented on a gross basis for the periods indicated:

		September 30, 2020				December 31, 2019
	Location in our Consolidated Balance Sheets	Assets		(Liabilities)		Assets		(Liabilities)
Derivatives designated as hedging instruments		(Thousands of dollars)
Commodity contracts (a)
Financial contracts (b)	Other current assets	$	46,451	$	(60,373)	$	64,858	$	(26,997)
	Other deferred credits	—		—		1,591		(2,599)
Interest-rate contracts	Other current liabilities	—		—		—		(90,161)
	Other assets/other deferred credits	—		(231,991)		581		(111,780)
Total derivatives designated as hedging instruments		46,451		(292,364)		67,030		(231,537)
Derivatives not designated as hedging instruments
Commodity contracts (a)
Financial contracts (b)		408		(376)		—		—
Total derivatives not designated as hedging instruments		408		(376)		—		—
Total derivatives		$	46,859	$	(292,740)	$	67,030	$	(231,537)

(a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us.

(b) - At September 30, 2020, our derivative net liability positions under master-netting arrangements for financial contracts were fully offset by $13.9 million of cash collateral.

Notional Amounts of Derivative Instruments

The following table sets forth the notional quantities for derivative instruments held for the periods indicated:

		September 30, 2020				December 31, 2019
	Contract Type	Purchased/ Payor		Sold/ Receiver		Purchased/ Payor		Sold/ Receiver
Derivatives designated as hedging instruments:
Cash flow hedges
Fixed price
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
- Crude oil and NGLs (MMBbl)	Futures	15.3		(22.7)		7.9		(17.4)
Basis
- Natural gas (Bcf)	Futures	1.7		(40.9)		—		(59.0)
Interest-rate contracts (Billions of dollars)	Swaps	$	1.1	$	—	$	3.1	$	—
Derivatives not designated as hedging instruments:
Fixed price
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—
- Crude oil and NGLs (MMBbl)	Futures	0.2		(0.2)		—		—
Basis
- Natural gas (Bcf)	Futures	1.5		(1.5)		—		—

Schedule of Cash Flow Hedging Instruments Effect on Comprehensive Income (Loss)

The following table sets forth the unrealized change in fair value of cash flow hedges in other comprehensive loss for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Commodity contracts	$	(29,667)	$	32,169	$	18,472	$	43,877
Interest-rate contracts	9,213		(128,041)		(237,200)		(303,351)
Total unrealized change in fair value of cash flow hedges in other comprehensive loss	$	(20,454)	$	(95,872)	$	(218,728)	$	(259,474)

Schedule of Cash Flow Hedging Instruments Effect on Income (Loss)

The following table sets forth the effect of cash flow hedges on net income for the periods indicated:

	Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income	Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2020		2019		2020		2019
		(Thousands of dollars)
Commodity contracts	Commodity sales revenues	$	2,167	$	38,234	$	100,304	$	85,375
	Cost of sales and fuel	(1,568)		(19,706)		(31,057)		(32,751)
Interest-rate contracts (a)	Interest expense	(8,998)		(6,903)		(83,817)		(14,222)
Total change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income on derivatives		$	(8,399)	$	11,625	$	(14,570)	$	38,402

(a) - The nine months ended September 30, 2020, includes a loss of $48.3 million on the settlement of our remaining $1.3 billion interest-rate swaps used to hedge our LIBOR-based interest payments.

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DEBT DEBT (Tables)

9 Months Ended

Sep. 30, 2020

Debt Instrument [Line Items]

Debt [Table Text Block]

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

	September 30, 2020		December 31, 2019
	(Thousands of dollars)
Commercial paper outstanding, bearing a weighted-average interest rate of 2.16% as of December 31, 2019	$	—	$	220,000
Senior unsecured obligations:
$1,500,000 term loan at 2.7% as of December 31, 2019, due November 2021	—		1,250,000
$700,000 at 4.25% due February 2022	547,397		547,397
$900,000 at 3.375% due October 2022	900,000		900,000
$425,000 at 5.0% due September 2023	425,000		425,000
$500,000 at 7.5% due September 2023	500,000		500,000
$500,000 at 2.75% due September 2024	500,000		500,000
$500,000 at 4.9% due March 2025	500,000		500,000
$400,000 at 2.2% due September 2025	387,000		—
$600,000 at 5.85% due January 2026	600,000		—
$500,000 at 4.0% due July 2027	500,000		500,000
$800,000 at 4.55% due July 2028	800,000		800,000
$100,000 at 6.875% due September 2028	100,000		100,000
$700,000 at 4.35% due March 2029	700,000		700,000
$750,000 at 3.4% due September 2029	714,251		750,000
$850,000 at 3.1% due March 2030	780,093		—
$600,000 at 6.35% due January 2031	600,000		—
$400,000 at 6.0% due June 2035	400,000		400,000
$600,000 at 6.65% due October 2036	600,000		600,000
$600,000 at 6.85% due October 2037	600,000		600,000
$650,000 at 6.125% due February 2041	650,000		650,000
$400,000 at 6.2% due September 2043	400,000		400,000
$700,000 at 4.95% due July 2047	689,006		700,000
$1,000,000 at 5.2% due July 2048	1,000,000		1,000,000
$750,000 at 4.45% due September 2049	723,736		750,000
$500,000 at 4.5% due March 2050	453,585		—
$300,000 at 7.15% due January 2051	300,000		—
Guardian Pipeline
Weighted average 7.85% due December 2022	15,570		21,307
Total debt	14,385,638		12,813,704
Unamortized portion of terminated swaps	13,743		15,032
Unamortized debt issuance costs and discounts	(142,392)		(121,329)
Current maturities of long-term debt	(7,650)		(7,650)
Short-term borrowings (a)	—		(220,000)
Long-term debt	$	14,249,339	$	12,479,757

(a) - Individual issuances of commercial paper under our commercial paper program generally mature in 90 days or less.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

9 Months Ended

Sep. 30, 2020

Accumulated Other Comprehensive Loss

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

	Risk- Management Assets/Liabilities (a)		Retirement and Other Postretirement Benefit Plan Obligations (a) (b)		Risk- Management Assets/Liabilities of Unconsolidated Affiliates (a)		Accumulated Other Comprehensive Loss (a)
	(Thousands of dollars)
January 1, 2020	$	(233,520)	$	(131,481)	$	(8,999)	$	(374,000)
Other comprehensive income (loss) before reclassifications	(168,421)		59		(10,893)		(179,255)
Amounts reclassified to net income (c)	11,210		10,626		801		22,637
Other comprehensive income (loss)	(157,211)		10,685		(10,092)		(156,618)
September 30, 2020	$	(390,731)	$	(120,796)	$	(19,091)	$	(530,618)

(a) - All amounts are presented net of tax.

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

(c) - See Note C for details of amounts reclassified to net income for risk-management assets/liabilities and Note H for retirement and other postretirement benefit plan obligations.

Schedule of Accumulated Other Comprehensive Loss for Risk-Management Assets/Liabilities [Table Text Block]

The following table sets forth information about the balance of accumulated other comprehensive loss at September 30, 2020, representing unrealized gains (losses) related to risk-management assets and liabilities:

	Risk- Management Assets/Liabilities (a)
	(Thousands of dollars)
Commodity derivative instruments expected to be realized within the next 15 months (b)	$	(10,988)
Settled interest-rate swaps to be recognized over the life of the long-term, fixed-rate debt (c)	(201,110)
Interest-rate swaps with future settlement dates expected to be amortized over the life of long-term debt	(178,633)
Accumulated other comprehensive loss at September 30, 2020	$	(390,731)

(a) - All amounts are presented net of tax.

(b) - Based on September 30, 2020, commodity prices, we expect $8.4 million in net losses, net of tax, over the next 12 months and $2.6 million in net losses, net of tax, thereafter.

(c) - We expect net losses of $30.3 million, net of tax, will be reclassified into earnings during the next 12 months.

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EARNINGS PER SHARE EARNINGS PER SHARE (Tables)

9 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share

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

	Three Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	312,041	445,103	$	0.70
Diluted EPS
Effect of dilutive securities	—		407
Net income available for common stock and common stock equivalents	$	312,041	445,510	$	0.70

	Three Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	308,880	413,816	$	0.75
Diluted EPS
Effect of dilutive securities	—		1,762
Net income available for common stock and common stock equivalents	$	308,880	415,578	$	0.74

	Nine Months Ended September 30, 2020
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	303,955	426,369	$	0.71
Diluted EPS
Effect of dilutive securities	—		628
Net income available for common stock and common stock equivalents	$	303,955	426,997	$	0.71

	Nine Months Ended September 30, 2019
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS
Net income available for common stock	$	957,501	413,443	$	2.32
Diluted EPS
Effect of dilutive securities	—		1,834
Net income available for common stock and common stock equivalents	$	957,501	415,277	$	2.31

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EMPLOYEE BENEFIT PLANS EMPLOYEE BENEFIT PLANS (Tables)

9 Months Ended

Sep. 30, 2020

Defined Benefit Plan [Abstract]

Components of net periodic benefit cost for retirement and other postretirement benefit plans

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

	Retirement Benefits				Other Postretirement Benefits
	Three Months Ended				Three Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	2,036	$	1,954	$	115	$	117
Interest cost	4,574		5,126		442		509
Expected return on plan assets	(6,232)		(5,892)		(722)		(570)
Amortization of prior service cost (credit) (a)	28		—		—		(57)
Amortization of net loss (a)	4,571		3,158		1		74
Net periodic benefit cost (income)	$	4,977	$	4,346	$	(164)	$	73

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $1.1 million and $0.7 million reclassified to income tax expense for the three months ended September 30, 2020 and 2019, respectively.

	Retirement Benefits				Other Postretirement Benefits
	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Components of net periodic benefit cost (income)
Service cost	$	6,108	$	5,862	$	345	$	351
Interest cost	13,722		15,378		1,326		1,527
Expected return on plan assets	(18,696)		(17,676)		(2,166)		(1,710)
Amortization of prior service cost (credit) (a)	84		—		—		(171)
Amortization of net loss (a)	13,713		9,474		3		222
Net periodic benefit cost (income)	$	14,931	$	13,038	$	(492)	$	219

(a) - These components of net periodic benefit cost (income) are recognized in accumulated other comprehensive loss and are reclassified to other income (expense) in our Consolidated Statements of Income, with related income tax benefits of $3.2 million and $2.2 million reclassified to income tax expense for the nine months ended September 30, 2020 and 2019, respectively.

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UNCONSOLIDATED AFFILIATES (Tables)

9 Months Ended

Sep. 30, 2020

Equity In Net Earnings From Investments

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Table Text Block]

The following table sets forth our equity in net earnings (loss) from investments for the periods indicated:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Northern Border Pipeline	$	22,037	$	16,102	$	57,028	$	50,593
Overland Pass Pipeline	8,007		15,481		30,090		48,340
Roadrunner	8,033		7,421		21,275		19,836
Other	(31)		(1,428)		(392)		(3,594)
Equity in net earnings from investments	$	38,046	$	37,576	$	108,001	$	115,175
Impairment of equity investments	$	—	$	—	$	(37,730)	$	—

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LEASES (Tables)

9 Months Ended

Sep. 30, 2020

Leases [Abstract]

Lease Assets and Liabilities Included in the Consolidated Balance Sheet[Table Text Block]

The following table sets forth supplemental cash flow information related to our leases:

	Nine Months Ended
	September 30,
	2020		2019
	(Thousands of dollars)
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows for operating leases	$	9,662	$	4,972
Financing cash flows for finance lease	$	1,443	$	1,307
Right-of-use assets obtained in exchange for operating lease liabilities (noncash)	$	99,197	$	3,663

Lessee, Operating Lease, Liability, Maturity [Table Text Block]

The following table sets forth the maturity of our lease liabilities as of September 30, 2020:

	Finance Lease		Operating Leases
	(Millions of dollars)
Remainder of 2020	$	1.2	$	4.1
2021	4.5		16.4
2022	4.5		15.1
2023	4.5		13.8
2024	4.5		12.5
2025 and beyond	17.1		58.2
Total lease payments	36.3		120.1
Less: Interest	11.5		15.6
Present value of lease liabilities	$	24.8	$	104.5

Finance Lease, Liability, Maturity [Table Text Block]

The following table sets forth the maturity of our lease liabilities as of September 30, 2020:

	Finance Lease		Operating Leases
	(Millions of dollars)
Remainder of 2020	$	1.2	$	4.1
2021	4.5		16.4
2022	4.5		15.1
2023	4.5		13.8
2024	4.5		12.5
2025 and beyond	17.1		58.2
Total lease payments	36.3		120.1
Less: Interest	11.5		15.6
Present value of lease liabilities	$	24.8	$	104.5

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REVENUE REVENUE (Tables)

9 Months Ended

Sep. 30, 2020

Revenue from Contract with Customer [Abstract]

Contract with Customer, Asset and Liability [Table Text Block]

The following table sets forth the balances in contract liabilities for the periods indicated:

Contract Liabilities	(Millions of dollars)
Balance at December 31, 2019 (a)	$	57.1
Revenue recognized included in beginning balance (b)	(35.1)
Net additions	24.3
Balance at September 30, 2020 (c)	$	46.3

(a) - Contract liabilities of $22.2 million and $34.9 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

(b) - Includes a contract settlement in the second quarter 2020 of revenue previously deferred.

(c) - Contract liabilities of $27.6 million and $18.7 million are included in other current liabilities and other deferred credits, respectively, in our Consolidated Balance Sheet.

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

The following table presents aggregate value allocated to unsatisfied performance obligations as of September 30, 2020, and the amounts we expect to recognize in revenue in future periods, related primarily to firm transportation and storage contracts with remaining contract terms ranging from one month to 24 years:

Expected Period of Recognition in Revenue	(Millions of dollars)
Remainder of 2020	$	87.1
2021	320.0
2022	259.9
2023	230.9
2024 and beyond	901.0
Total estimated transaction price allocated to unsatisfied performance obligations	$	1,798.9

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SEGMENTS (Tables)

9 Months Ended

Sep. 30, 2020

Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]

Segments

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

Three Months Ended September 30, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	239,810	$	1,658,123	$	—	$	1,897,933
Residue natural gas sales	178,492		—		3,998		182,490
Gathering, processing and exchange services revenue	36,459		132,210		—		168,669
Transportation and storage revenue	—		39,774		113,047		152,821
Other	4,644		2,110		251		7,005
Total revenues (c)	459,405		1,832,217		117,296		2,408,918
Cost of sales and fuel (exclusive of depreciation and operating costs)	(207,519)		(1,289,667)		(3,389)		(1,500,575)
Operating costs	(69,351)		(101,223)		(34,567)		(205,141)
Equity in net earnings (loss) from investments	(42)		8,018		30,070		38,046
Noncash compensation expense and other	655		1,898		427		2,980
Segment adjusted EBITDA	$	183,148	$	451,243	$	109,837	$	744,228
Depreciation and amortization	$	(66,459)	$	(71,534)	$	(14,243)	$	(152,236)
Capital expenditures	$	63,030	$	298,891	$	12,978	$	374,899

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $541.7 million, of which $495.4 million related to revenues within the segment, and cost of sales and fuel of $137.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $71.8 million and cost of sales and fuel of $9.6 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $235.6 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,897,933	$	(224,731)	$	1,673,202
Residue natural gas sales	182,490		(5,897)		176,593
Gathering, processing and exchange services revenue	168,669		—		168,669
Transportation and storage revenue	152,821		(3,597)		149,224
Other	7,005		(429)		6,576
Total revenues (a)	$	2,408,918	$	(234,654)	$	2,174,264
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,500,575)	$	234,901	$	(1,265,674)
Operating costs	$	(205,141)	$	212	$	(204,929)
Depreciation and amortization	$	(152,236)	$	(1,009)	$	(153,245)
Equity in net earnings from investments	$	38,046	$	—	$	38,046
Capital expenditures	$	374,899	$	5,143	$	380,042

(a) - Noncustomer revenue for the three months ended September 30, 2020, totaled $4.0 million related primarily to gains from derivatives on commodity contracts.

Three Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	244,932	$	1,746,630	$	—	$	1,991,562
Residue natural gas sales	185,303		—		231		185,534
Gathering, processing and exchange services revenue	42,795		105,179		—		147,974
Transportation and storage revenue	—		46,407		119,924		166,331
Other	3,182		2,291		1,393		6,866
Total revenues (c)	476,212		1,900,507		121,548		2,498,267
Cost of sales and fuel (exclusive of depreciation and operating costs)	(210,739)		(1,438,206)		(381)		(1,649,326)
Operating costs	(91,227)		(114,903)		(40,170)		(246,300)
Equity in net earnings (loss) from investments	(1,837)		15,890		23,523		37,576
Noncash compensation expense and other	2,883		4,174		(701)		6,356
Segment adjusted EBITDA	$	175,292	$	367,462	$	103,819	$	646,573
Depreciation and amortization	$	(55,781)	$	(50,419)	$	(14,330)	$	(120,530)
Capital expenditures	$	245,745	$	738,038	$	27,767	$	1,011,550

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $379.7 million, of which $315.7 million related to revenues within the segment, and cost of sales and fuel of $129.5 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $72.3 million and cost of sales and fuel of $5.1 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $244.2 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Three Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	1,991,562	$	(230,080)	$	1,761,482
Residue natural gas sales	185,534		(567)		184,967
Gathering, processing and exchange services revenue	147,974		—		147,974
Transportation and storage revenue	166,331		(4,010)		162,321
Other	6,866		(382)		6,484
Total revenues (a)	$	2,498,267	$	(235,039)	$	2,263,228
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(1,649,326)	$	234,798	$	(1,414,528)
Operating costs	$	(246,300)	$	1,165	$	(245,135)
Depreciation and amortization	$	(120,530)	$	(900)	$	(121,430)
Equity in net earnings from investments	$	37,576	$	—	$	37,576
Capital expenditures	$	1,011,550	$	7,624	$	1,019,174

(a) - Noncustomer revenue for the three months ended September 30, 2019, totaled $89.0 million related primarily to gains from derivatives on commodity contracts.

Nine Months Ended September 30, 2020	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	569,308	$	4,429,414	$	—	$	4,998,722
Residue natural gas sales	518,435		—		6,033		524,468
Gathering, processing and exchange services revenue	110,345		370,920		—		481,265
Transportation and storage revenue	—		131,410		353,188		484,598
Other	11,106		6,779		916		18,801
Total revenues (c)	1,209,194		4,938,523		360,137		6,507,854
Cost of sales and fuel (exclusive of depreciation and operating costs)	(541,910)		(3,473,575)		(5,096)		(4,020,581)
Operating costs	(232,489)		(297,771)		(100,966)		(631,226)
Equity in net earnings (loss) from investments	(1,385)		31,083		78,303		108,001
Noncash compensation expense and other	(1,865)		1,541		(184)		(508)
Segment adjusted EBITDA	$	431,545	$	1,199,801	$	332,194	$	1,963,540
Depreciation and amortization	$	(180,634)	$	(198,440)	$	(43,937)	$	(423,011)
Impairment charges	$	(564,353)	$	(77,401)	$	—	$	(641,754)
Investments in unconsolidated affiliates	$	2,276	$	426,621	$	361,476	$	790,373
Total assets	$	6,437,301	$	13,449,529	$	2,082,846	$	21,969,676
Capital expenditures	$	362,811	$	1,504,881	$	40,478	$	1,908,170

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1,454.0 million, of which $1,306.2 million related to revenues within the segment, and cost of sales and fuel of $375.0 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $225.6 million and cost of sales and fuel of $22.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $557.1 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2020	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	4,998,722	$	(513,170)	$	4,485,552
Residue natural gas sales	524,468		(10,860)		513,608
Gathering, processing and exchange services revenue	481,265		—		481,265
Transportation and storage revenue	484,598		(11,033)		473,565
Other	18,801		(1,126)		17,675
Total revenues (a)	$	6,507,854	$	(536,189)	$	5,971,665
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(4,020,581)	$	537,521	$	(3,483,060)
Operating costs	$	(631,226)	$	(5,207)	$	(636,433)
Depreciation and amortization	$	(423,011)	$	(3,003)	$	(426,014)
Impairment charges	$	(641,754)	$	—	$	(641,754)
Equity in net earnings from investments	$	108,001	$	—	$	108,001
Investments in unconsolidated affiliates	$	790,373	$	—	$	790,373
Total assets	$	21,969,676	$	811,200	$	22,780,876
Capital expenditures	$	1,908,170	$	15,833	$	1,924,003

(a) - Noncustomer revenue for the nine months ended September 30, 2020, totaled $103.0 million related primarily to gains from derivatives on commodity contracts.

Nine Months Ended September 30, 2019	Natural Gas Gathering and Processing		Natural Gas Liquids (a)		Natural Gas Pipelines (b)		Total Segments
	(Thousands of dollars)
NGL and condensate sales	$	890,021	$	5,826,297	$	—	$	6,716,318
Residue natural gas sales	725,672		—		1,242		726,914
Gathering, processing and exchange services revenue	126,073		309,571		—		435,644
Transportation and storage revenue	—		141,384		350,029		491,413
Other	11,287		7,313		4,208		22,808
Total revenues (c)	1,753,053		6,284,565		355,479		8,393,097
Cost of sales and fuel (exclusive of depreciation and operating costs)	(971,397)		(4,914,452)		(3,785)		(5,889,634)
Operating costs	(271,236)		(340,274)		(113,043)		(724,553)
Equity in net earnings (loss) from investments	(4,660)		49,406		70,429		115,175
Noncash compensation expense and other	8,399		12,618		1,931		22,948
Segment adjusted EBITDA	$	514,159	$	1,091,863	$	311,011	$	1,917,033
Depreciation and amortization	$	(162,014)	$	(143,166)	$	(42,653)	$	(347,833)
Investments in unconsolidated affiliates	$	35,252	$	445,755	$	389,504	$	870,511
Total assets	$	6,546,417	$	11,662,489	$	2,083,773	$	20,292,679
Capital expenditures	$	674,115	$	1,969,138	$	77,861	$	2,721,114

(a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1.0 billion, of which $853.0 million related to revenues within the segment, and cost of sales and fuel of $364.9 million.

(b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $214.7 million and cost of sales and fuel of $14.4 million.

(c) - Intersegment revenues for the Natural Gas Gathering and Processing segment totaled $897.9 million. Intersegment revenues for the Natural Gas Liquids and Natural Gas Pipelines segments were not material.

Nine Months Ended September 30, 2019	Total Segments		Other and Eliminations		Total
	(Thousands of dollars)
Reconciliations of total segments to consolidated
NGL and condensate sales	$	6,716,318	$	(878,958)	$	5,837,360
Residue natural gas sales	726,914		(567)		726,347
Gathering, processing and exchange services revenue	435,644		—		435,644
Transportation and storage revenue	491,413		(11,827)		479,586
Other	22,808		(984)		21,824
Total revenues (a)	$	8,393,097	$	(892,336)	$	7,500,761
Cost of sales and fuel (exclusive of depreciation and operating costs)	$	(5,889,634)	$	892,935	$	(4,996,699)
Operating costs	$	(724,553)	$	964	$	(723,589)
Depreciation and amortization	$	(347,833)	$	(2,719)	$	(350,552)
Equity in net earnings from investments	$	115,175	$	—	$	115,175
Investments in unconsolidated affiliates	$	870,511	$	—	$	870,511
Total assets	$	20,292,679	$	1,043,228	$	21,335,907
Capital expenditures	$	2,721,114	$	18,224	$	2,739,338

(a) - Noncustomer revenue for the nine months ended September 30, 2019, totaled $129.9 million related primarily to gains from derivatives on commodity contracts.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2020		2019		2020		2019
	(Thousands of dollars)
Reconciliation of net income to total segment adjusted EBITDA
Net income	$	312,316	$	309,155	$	304,780	$	958,326
Add:
Interest expense, net of capitalized interest	176,371		129,577		535,955		362,490
Depreciation and amortization	153,245		121,430		426,014		350,552
Income tax expense	106,555		97,365		94,300		274,234
Impairment charges	—		—		641,754		—
Noncash compensation expense	1,606		9,757		1,261		20,412
Other corporate costs and equity AFUDC (a)	(5,865)		(20,711)		(40,524)		(48,981)
Total segment adjusted EBITDA	$	744,228	$	646,573	$	1,963,540	$	1,917,033

(a) - The three and nine months ended September 30, 2020, include corporate gains of $2.2 million and $22.2 million, respectively, on extinguishment of debt related to open market repurchases.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Entity Information [Line Items]
Goodwill	$ 527,592		$ 527,592		$ 680,996
Impairment of equity investments	0	$ 0	37,730	$ 0
Natural Gas Gathering And Processing [Member]
Entity Information [Line Items]
Impairment of long-lived assets			380,500
Impairment of intangible assets			19,900
Goodwill	$ 0		0		153,404
Goodwill impairment charge			$ 153,400
Natural Gas Gathering And Processing [Member] | Venice Energy Services Company [Member]
Entity Information [Line Items]
Equity Method Investment, Ownership Percentage	10.20%		10.20%
Impairment of equity investments - goodwill			$ 22,300
Impairment of equity investments			30,500
Natural Gas Liquids
Entity Information [Line Items]
Impairment of long-lived assets			70,200
Goodwill	$ 371,217		$ 371,217		371,217
Natural Gas Liquids | Chisholm Pipeline Company [Member]
Entity Information [Line Items]
Equity Method Investment, Ownership Percentage	50.00%		50.00%
Impairment of equity investments			$ 7,200
Natural Gas Pipelines
Entity Information [Line Items]
Goodwill	$ 156,375		$ 156,375		$ 156,375

XML

FAIR VALUE MEASUREMENTS - Part 1 (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash held - offsetting derivative net asset positions under master-netting arrangements	$ 0	$ 0
Cash posted - total	48,200	8,800
Cash posted - offsetting derivative net liability positions under master-netting arrangements	13,900
Cash posted - remaining in excess of derivative net liability positions included in consolidated Balance Sheets	34,300
Long-term debt, Fair Value	14,900,000	13,800,000
Long-term debt	14,300,000	12,500,000
Fair Value, Recurring [Member] | Estimate of Fair Value Measurement [Member]
Derivative assets
Derivative asset, fair value, gross	46,859	67,030
Derivative liability, fair value, gross	(292,740)	(231,537)
Fair Value, Recurring [Member] | Estimate of Fair Value Measurement [Member] | Financial Contracts [Member]
Derivative assets
Derivative asset, fair value, gross	46,859	66,449
Derivative liability, fair value, gross	(60,749)	(29,596)
Fair Value, Recurring [Member] | Estimate of Fair Value Measurement [Member] | Interest-rate contracts
Derivative assets
Interest-rate contracts		581
Derivative liabilities
Interest rate derivative liabilities, at fair value	(231,991)	(201,941)
Fair Value, Recurring [Member]
Derivative assets
Derivative assets	0	38,442
Derivative assets netting	(46,859)	(28,588)
Derivative liabilities
Derivative liabilities	(231,991)	(202,949)
Derivative liabilities netting	60,749	28,588
Fair Value, Recurring [Member] | Financial Contracts [Member]
Derivative assets
Derivative assets	0	37,861
Derivative assets netting	(46,859)	(28,588)
Derivative liabilities
Derivative liabilities	0	(1,008)
Derivative liabilities netting	60,749	28,588
Fair Value, Recurring [Member] | Interest-rate contracts
Derivative assets
Interest-rate contracts		581
Derivative assets netting		0
Derivative liabilities
Interest rate derivative liabilities, at fair value	(231,991)	(201,941)
Derivative liabilities netting	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets
Derivative asset, fair value, gross	4,963	10,892
Derivative liability, fair value, gross	(13,509)	(4,811)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Contracts [Member]
Derivative assets
Derivative asset, fair value, gross	4,963	10,892
Derivative liability, fair value, gross	(13,509)	(4,811)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Interest-rate contracts
Derivative assets
Interest-rate contracts		0
Derivative liabilities
Interest rate derivative liabilities, at fair value	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets
Derivative asset, fair value, gross	0	581
Derivative liability, fair value, gross	(231,991)	(201,941)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Contracts [Member]
Derivative assets
Derivative asset, fair value, gross	0	0
Derivative liability, fair value, gross	0	0
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest-rate contracts
Derivative assets
Interest-rate contracts		581
Derivative liabilities
Interest rate derivative liabilities, at fair value	(231,991)	(201,941)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets
Derivative asset, fair value, gross	41,896	55,557
Derivative liability, fair value, gross	(47,240)	(24,785)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Contracts [Member]
Derivative assets
Derivative asset, fair value, gross	41,896	55,557
Derivative liability, fair value, gross	(47,240)	(24,785)
Fair Value, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Interest-rate contracts
Derivative assets
Interest-rate contracts		0
Derivative liabilities
Interest rate derivative liabilities, at fair value	$ 0	$ 0

XML

FAIR VALUE MEASUREMENTS - Part 2 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Fair Value, Assets And Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract]
Net assets (liabilities) at beginning of period	$ 5,583	$ 19,274	$ 30,772	$ 40,484
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	(6,194)	(12,380)	(29,471)	(38,044)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, New Level 3 Derivatives	(2,033)	2,728	(5,140)	17,528
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Unrealized Change Included in other comprehensive income (loss)	(2,700)	18,593	(1,505)	8,247
Net assets (liabilities) at end of period	(5,344)	28,215	(5,344)	28,215
Transfers in or out of level 3	$ 0	$ 0	$ 0	$ 0

XML

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 1 (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative, Fair Value [Line Items]
Assets	$ 46,859	$ 67,030
(Liabilities)	(292,740)	(231,537)
Derivative, Net Liability Position, Aggregate Fair Value	0
Cash posted - offsetting derivative net liability positions under master-netting arrangements	13,900
Derivatives designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	46,451	67,030
(Liabilities)	(292,364)	(231,537)
Derivatives not designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	408	0
(Liabilities)	(376)	0
Natural Gas Pipelines
Derivative, Fair Value [Line Items]
Derivative, Fair Value, Net	0	0
Other Current Assets [Member] | Commodity contracts | Financial contracts | Derivatives designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	46,451	64,858
(Liabilities)	(60,373)	(26,997)
Other Current Assets [Member] | Commodity contracts | Financial contracts | Derivatives not designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	408	0
(Liabilities)	(376)	0
Other Current Liabilities [Member] | Interest-rate contracts | Derivatives designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	0	0
(Liabilities)	0	(90,161)
Other Deferred Credits | Commodity contracts | Financial contracts | Derivatives designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	0	1,591
(Liabilities)	0	(2,599)
Other Deferred Credits | Interest-rate contracts | Derivatives designated as hedging instruments
Derivative, Fair Value [Line Items]
Assets	0	581
(Liabilities)	$ (231,991)	(111,780)
Interest-rate contracts | LIBOR Based Interest Payments [Member] | Cash Flow Hedging [Member] | Forward contracts
Derivative, Fair Value [Line Items]
Derivative, Notional Amount		$ 1,300,000

XML

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES, Part 2 (Details) $ in Millions	3 Months Ended		9 Months Ended	12 Months Ended
	Jun. 30, 2020 USD ($)	Mar. 31, 2020 USD ($)	Sep. 30, 2020 USD ($) MMBbls Bcf	Dec. 31, 2019 USD ($) Bcf MMBbls
Derivative [Line Items]
Realized Loss on Settled Interest Rate Swaps Recorded in AOCI	$ 48.3	$ 152.5	$ 48.3
Notional Amount Of Cash Flow Hedge Instruments Settled	1,300.0	750.0	1,300.0
Cash posted - offsetting derivative net liability positions under master-netting arrangements			$ 13.9
Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Fixed price | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			1.7	0
Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Fixed price | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			(40.9)	(59.0)
Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Basis | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			1.7	0
Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Basis | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			(40.9)	(59.0)
Designated as Hedging Instrument [Member] | Futures, forwards and swaps | - Crude oil and NGLs (MMBbl) | Fixed price | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls			15.3	7.9
Designated as Hedging Instrument [Member] | Futures, forwards and swaps | - Crude oil and NGLs (MMBbl) | Fixed price | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls			(22.7)	(17.4)
Designated as Hedging Instrument [Member] | Interest-rate contracts | Purchased/ Payor
Derivative [Line Items]
Derivative, Notional Amount			$ 1,100.0	$ 3,100.0
Designated as Hedging Instrument [Member] | Interest-rate contracts | Sold/ Receiver
Derivative [Line Items]
Derivative, Notional Amount			$ 0.0	$ 0.0
Not Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Fixed price | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			1.5	0
Not Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Fixed price | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			(1.5)	0
Not Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Basis | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			1.5	0
Not Designated as Hedging Instrument [Member] | Futures and swaps | - Natural gas (Bcf) | Basis | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | Bcf			(1.5)	0
Not Designated as Hedging Instrument [Member] | Futures, forwards and swaps | - Crude oil and NGLs (MMBbl) | Fixed price | Purchased/ Payor
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls			0.2	0
Not Designated as Hedging Instrument [Member] | Futures, forwards and swaps | - Crude oil and NGLs (MMBbl) | Fixed price | Sold/ Receiver
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls			(0.2)	0
LIBOR Based Interest Payments [Member] | Cash Flow Hedging [Member] | Forward contracts | Interest-rate contracts
Derivative [Line Items]
Derivative, Notional Amount				$ 1,300.0
Forecasted Debt Issuances [Member] | Cash Flow Hedging [Member] | Forward contracts | Interest-rate contracts
Derivative [Line Items]
Derivative, Notional Amount			$ 1,100.0	$ 1,800.0
Notes Payable from Public Offering Due 2025, 2030 and 2050 [Member]
Derivative [Line Items]
Senior notes, noncurrent		$ 1,750.0
Term Loan Agreement due 2021 [Member] | Parent Company
Derivative [Line Items]
Debt Instrument, Face Amount	$ 1,500.0		$ 1,500.0

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RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES Part 3 (Details) - Cash Flow Hedging [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized change in fair value of cash flow hedges in other comprehensive income (loss)	$ (20,454)	$ (95,872)	$ (218,728)	$ (259,474)
Change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income (loss) on derivatives	(8,399)	11,625	(14,570)	38,402
Commodity contracts
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized change in fair value of cash flow hedges in other comprehensive income (loss)	(29,667)	32,169	18,472	43,877
Commodity contracts | Commodity sales revenues
Derivative Instruments, Gain (Loss) [Line Items]
Change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income (loss) on derivatives	2,167	38,234	100,304	85,375
Commodity contracts | Cost of sales and fuel
Derivative Instruments, Gain (Loss) [Line Items]
Change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income (loss) on derivatives	(1,568)	(19,706)	(31,057)	(32,751)
Interest-rate contracts
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized change in fair value of cash flow hedges in other comprehensive income (loss)	9,213	(128,041)	(237,200)	(303,351)
Interest-rate contracts | Interest expense
Derivative Instruments, Gain (Loss) [Line Items]
Change in fair value of cash flow hedges reclassified from accumulated other comprehensive loss into net income (loss) on derivatives	$ (8,998)	$ (6,903)	$ (83,817)	$ (14,222)

XML

DEBT DEBT (Details) $ in Thousands	3 Months Ended				9 Months Ended
	Dec. 31, 2020 USD ($)	Sep. 30, 2020 USD ($) Rate	Jun. 30, 2020 USD ($) Rate	Mar. 31, 2020 USD ($) Rate	Sep. 30, 2020 USD ($) Rate	Dec. 31, 2019 USD ($) Rate
Debt Instrument [Line Items]
Total debt		$ 14,385,638			$ 14,385,638	$ 12,813,704
Unamortized Portion of Terminated Swaps		13,743			13,743	15,032
Unamortized debt issuance costs and discounts		(142,392)			(142,392)	(121,329)
Current maturities of long-term debt		(7,650)			(7,650)	(7,650)
Short-term borrowings		0			0	(220,000)
Long-term debt		14,249,339			14,249,339	12,479,757
Long-term Debt, Repurchased Face Amount		28,000			202,300
Repayments of Debt		25,400			177,700
Gain (loss) on extinguishment of debt		2,200			$ 22,200
Subsequent Event [Member]
Debt Instrument [Line Items]
Business Combination, Consideration Transferred	$ 27,000
$2.5 Billion Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Covenant Description					Among other things, these covenants include maintaining a ratio of net indebtedness to adjusted EBITDA (EBITDA, as defined in our $2.5 Billion 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 at September 30, 2020. In June 2020, we amended the $2.5 Billion Credit Agreement by, among other things, modifying the leverage ratio so that we may net up to $700 million of cash on hand against our consolidated indebtedness for purposes of calculating the ratio’s numerator for the fiscal quarters ending June 30, 2020, September 30, 2020, and December 31, 2020.
Line of Credit Facility, Amount Outstanding		$ 0			$ 0
Indebtedness To Adjusted Ebitda Current		4.6			4.6
Indebtedness To Adjusted EBITDA Maximum		5.0			5.0
Line of Credit Facility, Maximum Borrowing Capacity		$ 2,500,000			$ 2,500,000
Maximum amount of cash allowable to net against indebtedness for leverage ratio		700,000			700,000
$2.5 Billion Credit Agreement [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Indebtedness To Adjusted EBITDA From Acquisitions Maximum	5.5
Notes Payable from Public Offering Due 2026, 2031 and 2051 [Member]
Debt Instrument [Line Items]
Senior notes, noncurrent			$ 1,500,000
Proceeds from Debt, Net of Issuance Costs			1,480,000
Notes Payable from Public Offering Due 2025, 2030 and 2050 [Member]
Debt Instrument [Line Items]
Senior notes, noncurrent				$ 1,750,000
Proceeds from Debt, Net of Issuance Costs				1,730,000
Guardian Pipeline [Member] | Notes Payables 1 due 2022 [Member]
Debt Instrument [Line Items]
Total debt		$ 15,570			$ 15,570	21,307
Long-term Debt, Weighted Average Interest Rate, at Point in Time | Rate		7.85%			7.85%
Subsidiary Issuer [Member] | 3.375% Notes Payable due 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 900,000			$ 900,000
Total debt		$ 900,000			$ 900,000	900,000
Interest Rate (in hundredths) | Rate		3.375%			3.375%
Subsidiary Issuer [Member] | 5.0% Notes Payable due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 425,000			$ 425,000
Total debt		$ 425,000			$ 425,000	425,000
Interest Rate (in hundredths) | Rate		5.00%			5.00%
Subsidiary Issuer [Member] | 4.9% Notes Payable due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000			$ 500,000
Total debt		$ 500,000			$ 500,000	500,000
Interest Rate (in hundredths) | Rate		4.90%			4.90%
Subsidiary Issuer [Member] | 6.65% Notes Payable due 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 600,000			$ 600,000
Total debt		$ 600,000			$ 600,000	600,000
Interest Rate (in hundredths) | Rate		6.65%			6.65%
Subsidiary Issuer [Member] | 6.85% Notes Payable due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 600,000			$ 600,000
Total debt		$ 600,000			$ 600,000	600,000
Interest Rate (in hundredths) | Rate		6.85%			6.85%
Subsidiary Issuer [Member] | 6.125% Notes Payable due 2041 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 650,000			$ 650,000
Total debt		$ 650,000			$ 650,000	650,000
Interest Rate (in hundredths) | Rate		6.125%			6.125%
Subsidiary Issuer [Member] | 6.2% Notes Payable due 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 400,000			$ 400,000
Total debt		$ 400,000			$ 400,000	$ 400,000
Interest Rate (in hundredths) | Rate		6.20%			6.20%
Parent Company
Debt Instrument [Line Items]
Short-term Debt, Weighted Average Interest Rate, at Point in Time | Rate						2.16%
Commercial paper		$ 0			$ 0	$ 220,000
Parent Company | Term Loan Agreement due 2021 [Member]
Debt Instrument [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate | Rate						2.70%
Debt Instrument, Face Amount		1,500,000	1,500,000		1,500,000
Total debt		0			0	$ 1,250,000
Repayments of Debt			1,250,000
Parent Company | 4.25% Notes Payable due 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		700,000			700,000
Total debt		$ 547,397			$ 547,397	547,397
Interest Rate (in hundredths) | Rate		4.25%			4.25%
Parent Company | 7.5% Notes Payable due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000			$ 500,000
Total debt		$ 500,000			$ 500,000	500,000
Interest Rate (in hundredths) | Rate		7.50%			7.50%
Parent Company | 2.75% Notes Payable due 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000			$ 500,000
Total debt		$ 500,000			$ 500,000	500,000
Interest Rate (in hundredths) | Rate		2.75%			2.75%
Parent Company | 2.2% Notes Payable due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 400,000		$ 400,000	$ 400,000
Total debt		$ 387,000			$ 387,000	0
Interest Rate (in hundredths) | Rate		2.20%		2.20%	2.20%
Parent Company | 5.85% Notes Payable due 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 600,000	$ 600,000		$ 600,000
Total debt		$ 600,000			$ 600,000	0
Interest Rate (in hundredths) | Rate		5.85%	5.85%		5.85%
Parent Company | 4.0% Notes Payable due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000			$ 500,000
Total debt		$ 500,000			$ 500,000	500,000
Interest Rate (in hundredths) | Rate		4.00%			4.00%
Parent Company | 4.55% Notes Payable due 2028 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 800,000			$ 800,000
Total debt		$ 800,000			$ 800,000	800,000
Interest Rate (in hundredths) | Rate		4.55%			4.55%
Parent Company | 6.875% Notes Payable due 2028 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 100,000			$ 100,000
Total debt		$ 100,000			$ 100,000	100,000
Interest Rate (in hundredths) | Rate		6.875%			6.875%
Parent Company | 4.35% Notes Payable due 2029 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 700,000			$ 700,000
Total debt		$ 700,000			$ 700,000	700,000
Interest Rate (in hundredths) | Rate		4.35%			4.35%
Parent Company | 3.4% Notes Payable due 2029 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 750,000			$ 750,000
Total debt		$ 714,251			$ 714,251	750,000
Interest Rate (in hundredths) | Rate		3.40%			3.40%
Parent Company | 3.1% Notes Payable due 2030 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 850,000		$ 850,000	$ 850,000
Total debt		$ 780,093			$ 780,093	0
Interest Rate (in hundredths) | Rate		3.10%		3.10%	3.10%
Parent Company | 6.35% Notes Payable due 2031 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 600,000	$ 600,000		$ 600,000
Total debt		$ 600,000			$ 600,000	0
Interest Rate (in hundredths) | Rate		6.35%	6.35%		6.35%
Parent Company | 6.0% Notes Payable due 2035 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 400,000			$ 400,000
Total debt		$ 400,000			$ 400,000	400,000
Interest Rate (in hundredths) | Rate		6.00%			6.00%
Parent Company | 4.95% Notes Payable due 2047 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 700,000			$ 700,000
Total debt		$ 689,006			$ 689,006	700,000
Interest Rate (in hundredths) | Rate		4.95%			4.95%
Parent Company | 5.2% Notes Payable due 2048 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,000,000			$ 1,000,000
Total debt		$ 1,000,000			$ 1,000,000	1,000,000
Interest Rate (in hundredths) | Rate		5.20%			5.20%
Parent Company | 4.45% Notes Payable due 2049 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 750,000			$ 750,000
Total debt		$ 723,736			$ 723,736	750,000
Interest Rate (in hundredths) | Rate		4.45%			4.45%
Parent Company | 4.5% Notes Payable due 2050 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000		$ 500,000	$ 500,000
Total debt		$ 453,585			$ 453,585	0
Interest Rate (in hundredths) | Rate		4.50%		4.50%	4.50%
Parent Company | 7.15% Notes Payable due 2051 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 300,000	$ 300,000		$ 300,000
Total debt		$ 300,000			$ 300,000	$ 0
Interest Rate (in hundredths) | Rate		7.15%	7.15%		7.15%

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EQUITY (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended							9 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020
Common Stock Issued During Period, Shares, New Issues			29,900
Public Offering Price			$ 32.00
Common Stock Issued During Period, Value, New Issues			$ 937,000
Dividends, Per Share, Cash Paid		$ 0.935	$ 0.935	$ 0.935	$ 0.89	$ 0.865	$ 0.86
Dividends, Preferred Stock, Cash		$ 300	$ 300	$ 300
Preferred Stock, Dividends, Declared		$ 275	$ 275	$ 275	$ 275	$ 275	$ 275
Issued Under Equity Agreement [Member]
Common Stock Sold Under Equity Distribution Agreement		0
ONEOK [Member]
Aggregate Amount Of Common Shares Available For Issuance And Sale Under Equity Distribution Agreement		$ 1,000,000
Series E Preferred Stock [Member]
Preferred Stock, Dividend Rate, Percentage								5.50%
Subsequent Event [Member]
Common Stock, Dividends, Per Share, Declared	$ 0.935
Dividends Payable, Date of Record	Nov. 02, 2020
Dividends Payable, Date to be Paid	Nov. 13, 2020
Preferred Stock, Dividends, Declared	$ 300

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Risk management assets/liabilities - January 1			$ (233,520)				$ (233,520)
Retirement and other postretirement benefit plan obligations - January 1			(131,481)				(131,481)
Risk-management assets/liabilities of unconsolidated affiliates - January 1			(8,999)				(8,999)
Accumulated other comprehensive loss - January 1			(374,000)				(374,000)
Other comprehensive income (loss) before reclassification, risk-management assets/liabilities	$ (15,750)			$ (73,822)			(168,421)	$ (199,795)
Other comprehensive (income) loss before reclassification, retirement and postretirement benefit plan obligations							59
Other comprehensive income (loss) before reclassification, risk-management assets/liabilities of unconsolidated affiliates							(10,893)
Other comprehensive income (loss) before reclassifications							(179,255)
Other comprehensive income reclassification adjustment from AOCI for risk-management assets/liabilities, net of tax	5,361			(8,952)			11,210	(29,748)
Other comprehensive income, retirement and other postretirement benefit plans, reclassification adjustment from AOCI, net of tax							10,626
Other comprehensive income, reclassification adjustment from AOCI for other comprehensive income attributable to unconsolidated affiliates, net of tax							801
Other comprehensive income, reclassification adjustment included in net income, net of tax							22,637
Other comprehensive income (loss), risk-management assets/liabilities, after reclassification adjustment, net of tax							(157,211)
Other comprehensive (income) loss, retirement and other postretirement benefit plans, after reclassification adjustment, net of tax	3,562			2,465			10,685	7,271
Other comprehensive income (loss), risk-management assets/liabilities of unconsolidated affiliates, net of tax	1,112			(4,399)			(10,092)	(10,593)
Other comprehensive income (loss), net of tax	(5,715)	$ (25,517)	$ (125,386)	$ (84,708)	$ (66,872)	$ (81,285)	(156,618)	$ (232,865)
Risk management assets/liabilities - September 30	(390,731)						(390,731)
Retirement and other postretirement benefit plan obligations - September 30	(120,796)						(120,796)
Risk-management assets/liabilities of unconsolidated affiliates - September 30	(19,091)						(19,091)
Accumulated other comprehensive loss - September 30	(530,618)						(530,618)
Cash Flow Hedging [Member] | Commodity contracts
Unrealized gain loss on cash flow hedges net of tax accumulated other comprehensive income loss	(10,988)						(10,988)
Price risk cash flow hedge unrealized gain (loss) to be reclassified during next 12 months	(8,400)						(8,400)
Commodity cash flow hedge gain (loss) to be reclassified after next 12 months net	(2,600)						(2,600)
Cash Flow Hedging [Member] | Interest-rate contracts
Amount of accumulated other comprehensive income (loss) attributable primarily to settled interest-rate swaps.	(201,110)						(201,110)
Amount of accumulated other comprehensive income (loss) attributable primarily to forward starting interest-rate swaps.	(178,633)						(178,633)
Interest rate cash flow hedge gain (loss) to be reclassified during next 12 months, net	$ (30,300)						$ (30,300)

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EARNINGS PER SHARE EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Basic EPS
Net income available for common stock	$ 312,041	$ 308,880	$ 303,955	$ 957,501
Shares	445,103	413,816	426,369	413,443
Earnings per share, basic	$ 0.70	$ 0.75	$ 0.71	$ 2.32
Diluted EPS
Effect of dilutive securities	$ 0	$ 0	$ 0	$ 0
Effect of dilutive securities, number of shares	407	1,762	628	1,834
Net income available for common stock and common stock equivalents	$ 312,041	$ 308,880	$ 303,955	$ 957,501
Shares	445,510	415,578	426,997	415,277
Earnings per share, diluted	$ 0.70	$ 0.74	$ 0.71	$ 2.31

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EMPLOYEE BENEFIT PLANS EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Income tax benefits reclassified from accumulated other comprehensive loss to income tax expense
Income tax benefit	$ 1,100	$ 700	$ 3,200	$ 2,200
Other Postretirement Benefits Plan
Components of net periodic benefit cost (income)
Service cost	115	117	345	351
Interest cost	442	509	1,326	1,527
Expected return on plan assets	(722)	(570)	(2,166)	(1,710)
Amortization of prior service cost (credit)	0	(57)	0	(171)
Amortization of net loss	1	74	3	222
Net periodic benefit cost (income)	(164)	73	(492)	219
Retirement Benefits
Components of net periodic benefit cost (income)
Service cost	2,036	1,954	6,108	5,862
Interest cost	4,574	5,126	13,722	15,378
Expected return on plan assets	(6,232)	(5,892)	(18,696)	(17,676)
Amortization of prior service cost (credit)	28	0	84	0
Amortization of net loss	4,571	3,158	13,713	9,474
Net periodic benefit cost (income)	$ 4,977	$ 4,346	$ 14,931	$ 13,038

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UNCONSOLIDATED AFFILIATES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	$ 38,046	$ 37,576	$ 108,001	$ 115,175
Accounts Payable, Related Parties, Current	13,300		13,300		$ 13,500
Impairment of equity investments	0	0	(37,730)	0
Equity-method goodwill	16,500		16,500
Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Expenses from Transactions with Related Parties	35,800	41,900	108,400	124,200
Northern Border Pipeline
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	22,037	16,102	57,028	50,593
Overland Pass Pipeline
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	8,007	15,481	30,090	48,340
Roadrunner
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	8,033	7,421	21,275	19,836
Other Unconsolidated Affiliates
Schedule of Equity Method Investments [Line Items]
Equity in net earnings from investments	$ (31)	$ (1,428)	(392)	$ (3,594)
Natural Gas Liquids | Chisholm Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Impairment of equity investments			$ (7,200)
Equity Method Investment, Ownership Percentage	50.00%		50.00%
Natural Gas Gathering And Processing [Member] | Venice Energy Services Company [Member]
Schedule of Equity Method Investments [Line Items]
Impairment of equity investments			$ (30,500)
Equity Method Investment, Ownership Percentage	10.20%		10.20%
Impairment of equity investments - goodwill			$ (22,300)

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LEASES (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Jan. 01, 2020
Lessee, Operating Lease, Details [Line Items]
Operating cash flows for operating leases	$ 9,662	$ 4,972
Financing cash flows for finance lease	1,443	1,307
Right-of-use assets obtained in exchange for operating lease liabilities (noncash)	99,197	$ 3,663
Lease remaining balance related to lease entered in December 2019 [Member] [Member] [Member]
Lessee, Operating Lease, Details [Line Items]
Lease liability remaining balance	71,400
Right-of-use asset remaining balance	70,700
Term of contract			10 years
Certain Operating Leases Entered Into During The Period [Member]
Lessee, Operating Lease, Details [Line Items]
Lease liability remaining balance	16,200
Right-of-use asset remaining balance	$ 16,200
Weighted-Average Remaining Lease Term [Member]
Lessee, Operating Lease, Details [Line Items]
Operating Lease, Weighted Average Remaining Lease Term	8 years 6 months
Weighted-Average Discount Rate [Member]
Lessee, Operating Lease, Details [Line Items]
Operating Lease, Weighted Average Discount Rate, Percent	3.19%
Maturity of Finance Lease Liability
Lessee, Operating Lease, Details [Line Items]
Remainder of 2020	$ 1,200
2021	4,500
2022	4,500
2023	4,500
2024	4,500
2025 and beyond	17,100
Total lease payments	36,300
Less: Interest	11,500
Present value of lease liabilities	24,800
Maturity of Operating Lease Liabilities
Lessee, Operating Lease, Details [Line Items]
Remainder of 2020	4,100
2021	16,400
2022	15,100
2023	13,800
2024	12,500
2025 and beyond	58,200
Total lease payments	120,100
Less: Interest	15,600
Lease liability remaining balance	$ 104,500

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REVENUE REVENUE (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Contract with Customer, Liability [Abstract]
Contract with customer, liability	$ 46.3	$ 57.1
Revenue recognized included in beginning balance	(35.1)
Net additions	24.3
Contract with Customer, Liability, Current	27.6	22.2
Contract with Customer, Liability, Noncurrent	18.7	$ 34.9
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 1,798.9
Remaining Contract Terms [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Performance Obligation, Contract Term	one month to 24 years
2020 [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 87.1
2021 [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	320.0
2022 [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	259.9
2023 [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	230.9
Thereafter [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 901.0

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SEGMENTS (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Segment disclosure [Abstract]
Revenues	$ 2,174,264			$ 2,263,228			$ 5,971,665	$ 7,500,761
Cost of sales and fuel (exclusive of items shown separately below)	(1,265,674)			(1,414,528)			(3,483,060)	(4,996,699)
Operating costs	(204,929)			(245,135)			(636,433)	(723,589)
Equity in net earnings (loss) from investments	38,046			37,576			108,001	115,175
Depreciation and amortization	(153,245)			(121,430)			(426,014)	(350,552)
Impairment charges	0			0			(641,754)	0
Total assets	22,780,876			21,335,907			22,780,876	21,335,907	$ 21,812,121
Capital expenditures	380,042			1,019,174			1,924,003	2,739,338
Equity Method Investments	790,373			870,511			790,373	870,511	$ 861,844
Net income	312,316	$ 134,321	$ (141,857)	309,155	$ 311,963	$ 337,208	304,780	958,326
Interest expense, net of capitalized interest	176,371			129,577			535,955	362,490
Income tax expense (benefit)	106,555			97,365			94,300	274,234
Noncash compensation expense	1,606			9,757			1,261	20,412
Other corporate costs and noncash items	(5,865)			(20,711)			(40,524)	(48,981)
Gain (loss) on extinguishment of debt	2,200						22,200
Natural Gas Gathering And Processing [Member]
Segment disclosure [Abstract]
Revenues	459,405			476,212			1,209,194	1,753,053
Cost of sales and fuel (exclusive of items shown separately below)	(207,519)			(210,739)			(541,910)	(971,397)
Operating costs	(69,351)			(91,227)			(232,489)	(271,236)
Equity in net earnings (loss) from investments	(42)			(1,837)			(1,385)	(4,660)
Noncash compensation expense and other	655			2,883			(1,865)	8,399
Segment adjusted EBITDA	183,148			175,292			431,545	514,159
Depreciation and amortization	(66,459)			(55,781)			(180,634)	(162,014)
Impairment charges							(564,353)
Total assets	6,437,301			6,546,417			6,437,301	6,546,417
Capital expenditures	63,030			245,745			362,811	674,115
Equity Method Investments	2,276			35,252			2,276	35,252
Natural Gas Gathering And Processing [Member] | Natural Gas Gathering and Processing Intersegment [Member]
Segment disclosure [Abstract]
Revenues	235,600			244,200			557,100	897,900
Natural Gas Liquids
Segment disclosure [Abstract]
Revenues	1,832,217			1,900,507			4,938,523	6,284,565
Cost of sales and fuel (exclusive of items shown separately below)	(1,289,667)			(1,438,206)			(3,473,575)	(4,914,452)
Operating costs	(101,223)			(114,903)			(297,771)	(340,274)
Equity in net earnings (loss) from investments	8,018			15,890			31,083	49,406
Noncash compensation expense and other	1,898			4,174			1,541	12,618
Segment adjusted EBITDA	451,243			367,462			1,199,801	1,091,863
Depreciation and amortization	(71,534)			(50,419)			(198,440)	(143,166)
Impairment charges							(77,401)
Total assets	13,449,529			11,662,489			13,449,529	11,662,489
Capital expenditures	298,891			738,038			1,504,881	1,969,138
Equity Method Investments	426,621			445,755			426,621	445,755
Natural Gas Liquids | Natural Gas Liquids Regulated [Member]
Segment disclosure [Abstract]
Revenues	541,700			379,700			1,454,000	1,000,000
Cost of sales and fuel (exclusive of items shown separately below)	(137,500)			(129,500)			(375,000)	(364,900)
Natural Gas Pipelines
Segment disclosure [Abstract]
Revenues	117,296			121,548			360,137	355,479
Cost of sales and fuel (exclusive of items shown separately below)	(3,389)			(381)			(5,096)	(3,785)
Operating costs	(34,567)			(40,170)			(100,966)	(113,043)
Equity in net earnings (loss) from investments	30,070			23,523			78,303	70,429
Noncash compensation expense and other	427			(701)			(184)	1,931
Segment adjusted EBITDA	109,837			103,819			332,194	311,011
Depreciation and amortization	(14,243)			(14,330)			(43,937)	(42,653)
Impairment charges							0
Total assets	2,082,846			2,083,773			2,082,846	2,083,773
Capital expenditures	12,978			27,767			40,478	77,861
Equity Method Investments	361,476			389,504			361,476	389,504
Natural Gas Pipelines | Natural Gas Pipelines Regulated [Member]
Segment disclosure [Abstract]
Revenues	71,800			72,300			225,600	214,700
Cost of sales and fuel (exclusive of items shown separately below)	(9,600)			(5,100)			(22,400)	(14,400)
Total Segments [Member]
Segment disclosure [Abstract]
Revenues	2,408,918			2,498,267			6,507,854	8,393,097
Cost of sales and fuel (exclusive of items shown separately below)	(1,500,575)			(1,649,326)			(4,020,581)	(5,889,634)
Operating costs	(205,141)			(246,300)			(631,226)	(724,553)
Equity in net earnings (loss) from investments	38,046			37,576			108,001	115,175
Noncash compensation expense and other	2,980			6,356			(508)	22,948
Segment adjusted EBITDA	744,228			646,573			1,963,540	1,917,033
Depreciation and amortization	(152,236)			(120,530)			(423,011)	(347,833)
Impairment charges							(641,754)
Total assets	21,969,676			20,292,679			21,969,676	20,292,679
Capital expenditures	374,899			1,011,550			1,908,170	2,721,114
Equity Method Investments	790,373			870,511			790,373	870,511
Other and Eliminations
Segment disclosure [Abstract]
Revenues	(234,654)			(235,039)			(536,189)	(892,336)
Cost of sales and fuel (exclusive of items shown separately below)	234,901			234,798			537,521	892,935
Operating costs	212			1,165			(5,207)	964
Equity in net earnings (loss) from investments	0			0			0	0
Depreciation and amortization	(1,009)			(900)			(3,003)	(2,719)
Impairment charges							0
Total assets	811,200			1,043,228			811,200	1,043,228
Capital expenditures	5,143			7,624			15,833	18,224
Equity Method Investments	0			0			0	0
Operating Segments [Member] | Natural Gas Liquids | Natural Gas Liquids Regulated [Member]
Segment disclosure [Abstract]
Revenues	495,400			315,700			1,306,200	853,000
Noncustomer [Domain]
Segment disclosure [Abstract]
Revenues	4,000			89,000			103,000	129,900
NGL and Condensate Sales [Member]
Segment disclosure [Abstract]
Revenues	1,673,202			1,761,482			4,485,552	5,837,360
NGL and Condensate Sales [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	239,810			244,932			569,308	890,021
NGL and Condensate Sales [Member] | Natural Gas Liquids
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,658,123			1,746,630			4,429,414	5,826,297
NGL and Condensate Sales [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0			0			0	0
NGL and Condensate Sales [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,897,933			1,991,562			4,998,722	6,716,318
NGL and Condensate Sales [Member] | Other and Eliminations
Segment disclosure [Abstract]
Revenues	(224,731)			(230,080)			(513,170)	(878,958)
Residue Natural Gas Sales [Member]
Segment disclosure [Abstract]
Revenues	176,593			184,967			513,608	726,347
Residue Natural Gas Sales [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	178,492			185,303			518,435	725,672
Residue Natural Gas Sales [Member] | Natural Gas Liquids
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0			0			0	0
Residue Natural Gas Sales [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	3,998			231			6,033	1,242
Residue Natural Gas Sales [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	182,490			185,534			524,468	726,914
Residue Natural Gas Sales [Member] | Other and Eliminations
Segment disclosure [Abstract]
Revenues	(5,897)			(567)			(10,860)	(567)
Gathering, Processing and Exchange Services Revenue
Segment disclosure [Abstract]
Revenues	168,669			147,974			481,265	435,644
Gathering, Processing and Exchange Services Revenue | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	36,459			42,795			110,345	126,073
Gathering, Processing and Exchange Services Revenue | Natural Gas Liquids
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	132,210			105,179			370,920	309,571
Gathering, Processing and Exchange Services Revenue | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0			0			0	0
Gathering, Processing and Exchange Services Revenue | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	168,669			147,974			481,265	435,644
Gathering, Processing and Exchange Services Revenue | Other and Eliminations
Segment disclosure [Abstract]
Revenues	0			0			0	0
Transportation and Storage Revenue [Member]
Segment disclosure [Abstract]
Revenues	149,224			162,321			473,565	479,586
Transportation and Storage Revenue [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0			0			0	0
Transportation and Storage Revenue [Member] | Natural Gas Liquids
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	39,774			46,407			131,410	141,384
Transportation and Storage Revenue [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	113,047			119,924			353,188	350,029
Transportation and Storage Revenue [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	152,821			166,331			484,598	491,413
Transportation and Storage Revenue [Member] | Other and Eliminations
Segment disclosure [Abstract]
Revenues	(3,597)			(4,010)			(11,033)	(11,827)
Other [Member]
Segment disclosure [Abstract]
Revenues	6,576			6,484			17,675	21,824
Other [Member] | Natural Gas Gathering And Processing [Member]
Segment disclosure [Abstract]
Revenues	4,644			3,182			11,106	11,287
Other [Member] | Natural Gas Liquids
Segment disclosure [Abstract]
Revenues	2,110			2,291			6,779	7,313
Other [Member] | Natural Gas Pipelines
Segment disclosure [Abstract]
Revenues	251			1,393			916	4,208
Other [Member] | Total Segments [Member]
Segment disclosure [Abstract]
Revenues	7,005			6,866			18,801	22,808
Other [Member] | Other and Eliminations
Segment disclosure [Abstract]
Revenues	$ (429)			$ (382)			$ (1,126)	$ (984)