ONEOK Partners (OKS) 10-K 28 Feb 17 2016 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2016	Feb. 21, 2017	Jun. 30, 2016
Document Information [Line Items]
Entity Registrant Name	ONEOK Partners LP
Entity Central Index Key	909,281
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 6.9
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Common Units [Member]
Document Information [Line Items]
Limited Partners' Capital Account, Units Outstanding		212,837,980
Class B Units [Member]
Document Information [Line Items]
Limited Partners' Capital Account, Units Outstanding		72,988,252

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues [Abstract]
Commodity sales	$ 6,858,456	$ 6,098,343	$ 10,724,981
Services	2,060,003	1,662,725	1,466,684
Total revenues	8,918,459	7,761,068	12,191,665
Cost of sales and fuel (exclusive of items shown separately below)	6,496,124	5,641,052	10,088,548
Operations and maintenance	639,532	609,123	599,076
Depreciation and amortization	388,569	352,196	291,236
Impairment of long-lived assets (Note E)	0	83,673	0
General taxes	88,026	83,053	70,581
Gain on sale of assets	(9,916)	(6,108)	(6,599)
Operating income	1,316,124	998,079	1,148,823
Equity in net earnings from investments (Note L)	139,690	125,300	117,415
Impairment of equity investments (Note L)	0	(180,583)	(76,412)
Allowance for equity funds used during construction	209	2,179	14,937
Other income	1,324	126	5,447
Other expense	(4,394)	(4,174)	(4,299)
Interest expense (net of capitalized interest of $10,591, $36,572 and $54,813, respectively)	(366,789)	(338,911)	(281,908)
Income before income taxes	1,086,164	602,016	924,003
Income taxes (Note K)	(13,900)	(4,144)	(12,668)
Net income	1,072,264	597,872	911,335
Less: Net income attributable to noncontrolling interests	5,497	8,330	1,037
Net income attributable to ONEOK Partners, L.P.	1,066,767	589,542	910,298
Limited partners' interest in net income:
Net income attributable to ONEOK Partners, L.P.	1,066,767	589,542	910,298
General partner's interest in net income	(423,487)	(394,550)	(344,241)
Limited partners' interest in net income	$ 643,280	$ 194,992	$ 566,057
Limited partners' net income per unit, basic and diluted (Note J)	$ 2.25	$ 0.73	$ 2.33
Number of units used in computation (thousands)	285,826	267,281	243,306

CONSOLIDATED STATEMENTS OF INC3

CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Interest Costs, Capitalized During Period	$ 10,591	$ 36,572	$ 54,813
Net Income (Loss), Net of Tax, Per Outstanding Limited Partnership Unit, Diluted	$ 2.25	$ 0.73	$ 2.33

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income	$ 278,603	$ 275,411	$ 261,964	$ 256,286	$ 9,565	$ 229,665	$ 211,610	$ 147,032	$ 1,072,264	$ 597,872	$ 911,335
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(35,752)	47,500	(64,639)
Realized (gains) losses on derivatives recognized in net income									(10,717)	(67,034)	31,653
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,775)	(1,925)	0
Total other comprehensive income (loss)									(48,244)	(21,459)	(32,986)
Comprehensive income									1,024,020	576,413	878,349
Less: Comprehensive income attributable to noncontrolling interests									5,497	8,330	1,037
Comprehensive income attributable to ONEOK Partners, L.P.									$ 1,018,523	$ 568,083	$ 877,312

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 406	$ 5,079
Accounts receivable, net	872,310	593,448
Affiliate receivables	984	7,969
Natural gas and natural gas liquids in storage	140,034	128,084
Commodity imbalances	60,896	38,681
Materials and supplies	60,912	76,696
Other current assets	38,703	33,207
Total current assets	1,174,245	883,164
Property, plant and equipment
Property, plant and equipment	14,854,696	14,307,546
Accumulated depreciation and amortization	2,392,004	2,050,755
Net property, plant and equipment (Note E)	12,462,692	12,256,791
Investments and other assets
Investments in unconsolidated affiliates (Note L)	958,807	948,221
Goodwill and intangible assets (Note F)	812,977	824,877
Other assets	60,626	14,533
Total investments and other assets	1,832,410	1,787,631
Total assets	15,469,347	14,927,586
Current liabilities
Current maturities of long-term debt (Note G)	407,650	107,650
Short-term borrowings (Note G)	1,110,277	546,340
Accounts payable	862,436	605,431
Affiliate payables	68,233	27,137
Commodity imbalances	142,646	74,460
Accrued interest	87,130	102,615
Other current liabilities	146,004	116,667
Total current liabilities	2,824,376	1,580,300
Long-term debt, excluding current maturities (Note G)	6,291,307	6,695,312
Deferred credits and other liabilities	175,844	154,631
Commitments and contingencies (Note N)
ONEOK Partners, L.P. partners' equity (Note H):
General partner	226,039	231,344
Common units: 212,837,980 units issued and outstanding at December 31, 2016 and December 31, 2015	4,821,397	5,014,952
Class B units: 72,988,252 units issued and outstanding at December 31, 2016 and December 31, 2015	1,133,828	1,200,204
Accumulated other comprehensive loss (Note I)	(161,526)	(113,282)
Total ONEOK Partners, L.P. partners' equity	6,019,738	6,333,218
Noncontrolling interests in consolidated subsidiaries	158,082	164,125
Total equity	6,177,820	6,497,343
Total liabilities and equity	$ 15,469,347	$ 14,927,586

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Dec. 31, 2016	Dec. 31, 2015
ONEOK Partners, L.P. partners equity:
Common units issued (in shares)	212,837,980	212,837,980
Common units outstanding (in shares)	212,837,980	212,837,980
Class B units issued (in shares)	72,988,252	72,988,252
Class B units outstanding (in shares)	72,988,252	72,988,252

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating activities
Net income	$ 1,072,264	$ 597,872	$ 911,335
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	388,569	352,196	291,236
Impairment charges	0	264,256	76,412
Equity in net earnings from investments	(139,690)	(125,300)	(117,415)
Distributions received from unconsolidated affiliates	144,673	122,003	117,912
Deferred income taxes	12,070	4,765	10,832
Allowance for equity funds used during construction	(209)	(2,179)	(14,937)
Gain on sale of assets	(9,916)	(6,108)	(6,599)
Changes in assets and liabilities, net of acquisitions:
Accounts receivable	(285,992)	147,767	373,459
Affiliate receivables	6,985	584	632
Natural gas and natural gas liquids in storage	(11,950)	6,050	54,152
Accounts payable	285,888	(199,895)	(351,470)
Affiliate payables	41,096	(8,969)	(11,352)
Commodity imbalances, net	45,971	(4,083)	(93,234)
Accrued Interest	(15,485)	10,625	(721)
Risk-management assets and liabilities	(81,647)	(34,275)	36,444
Other assets and liabilities, net	34,150	(53,329)	33,134
Cash provided by operating activities	1,486,777	1,071,980	1,309,820
Investing activities
Capital expenditures (less allowance for equity funds used during construction)	(621,722)	(1,186,123)	(1,745,990)
Cash paid for acquisition, net of cash received	0	0	(814,934)
Contributions to unconsolidated affiliates	(68,275)	(27,540)	(1,063)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	52,044	33,915	21,107
Proceeds from sale of assets	25,359	3,825	7,817
Other	0	(12,607)	0
Cash used in investing activities	(612,594)	(1,188,530)	(2,533,063)
Financing activities
Cash distributions: General and limited partners	(1,332,003)	(1,230,475)	(1,052,245)
Cash distributions: Noncontrolling interests	(7,500)	(11,690)	(549)
Borrowing (repayment) of short-term borrowings, net	563,937	(508,956)	1,055,296
Issuance of long-term debt, net of discounts	1,000,000	798,896	0
Debt financing costs	(2,770)	(7,676)	0
Repayment of long-term debt	(1,107,650)	(7,650)	(7,650)
Issuance of common units, net of issuance costs	0	1,025,660	1,113,139
Contribution from general partner	0	20,990	23,252
Other	7,130	0	0
Cash provided (used in) by financing activities	(878,856)	79,099	1,131,243
Change in cash and cash equivalents	(4,673)	(37,451)	(92,000)
Cash and cash equivalents at beginning of period	5,079	42,530	134,530
Cash and cash equivalents at end of period	406	5,079	42,530
Supplemental cash flow information:
Cash paid for interest, net of amounts capitalized	361,635	307,036	271,314
Cash paid for income taxes	$ 789	$ 3,483	$ 1,336

CONSOLIDATED STATEMENT OF CHANG

CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	General Partner [Member]	Common Units [Member]	Class B Units [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interests in Consolidated Subsidiaries [Member]
Partners capital account, units, beginning balance at Dec. 31, 2013			159,007,854	72,988,252
Partners capital account beginning balance at Dec. 31, 2013	$ 4,998,696	$ 170,561	$ 3,459,920	$ 1,422,516	$ (58,837)	$ 4,536
Net income	911,335	344,241	394,503	171,554	0	1,037
Other comprehensive income (loss) (Note I)	(32,986)	0	$ 0	$ 0	(32,986)	0
Issuance of common units (in units) (Note H)			21,819,119	0
Issuance of common units (Note H)	1,108,456	0	$ 1,108,456	$ 0	0	0
Contribution from general partner (Note H)	23,155	23,155	0	0	0	0
West Texas LPG noncontrolling interest (Note O)	162,913	0	0	0	0	162,913
Distributions paid (Note H)	(1,052,794)	(326,043)	$ (506,507)	$ (219,695)	0	(549)
Partners capital account, units, ending balance at Dec. 31, 2014			180,826,973	72,988,252
Partners capital account ending balance at Dec. 31, 2014	6,118,775	211,914	$ 4,456,372	$ 1,374,375	(91,823)	167,937
Net income	597,872	394,550	138,520	56,472	0	8,330
Other comprehensive income (loss) (Note I)	(21,459)	0	$ 0	$ 0	(21,459)	0
Issuance of common units (in units) (Note H)			32,011,007	0
Issuance of common units (Note H)	1,023,767	0	$ 1,023,767	$ 0	0	0
Contribution from general partner (Note H)	20,990	20,990	0	0	0	0
Distributions paid (Note H)	(1,242,165)	(396,110)	(603,722)	(230,643)	0	(11,690)
Other	(437)	0	$ 15	$ 0	0	(452)
Partners capital account, units, ending balance at Dec. 31, 2015			212,837,980	72,988,252
Partners capital account ending balance at Dec. 31, 2015	6,497,343	231,344	$ 5,014,952	$ 1,200,204	(113,282)	164,125
Net income	1,072,264	423,487	479,013	164,267	0	5,497
Other comprehensive income (loss) (Note I)	(48,244)	0	0	0	(48,244)	0
Distributions paid (Note H)	(1,339,503)	(428,792)	(672,568)	(230,643)	0	(7,500)
Other	(4,040)	0	$ 0	$ 0	0	(4,040)
Partners capital account, units, ending balance at Dec. 31, 2016			212,837,980	72,988,252
Partners capital account ending balance at Dec. 31, 2016	$ 6,177,820	$ 226,039	$ 4,821,397	$ 1,133,828	$ (161,526)	$ 158,082

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Notes)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Organization and Nature of Operations - On January 31, 2017, we and ONEOK entered into the Merger Agreement, by and among ONEOK, Merger Sub, ONEOK Partners and ONEOK Partners GP, our general partner, pursuant to which ONEOK will acquire all of our outstanding common units representing limited partner interests in us not already directly or indirectly owned by ONEOK. Upon the terms and conditions set forth in the Merger Agreement, Merger Sub will be merged with and into ONEOK Partners, with ONEOK Partners continuing as a wholly owned subsidiary of ONEOK, in a taxable transaction to our common unitholders. For additional information on this transaction, see Note B . ONEOK Partners, L.P. is a publicly traded master limited partnership, organized under the laws of the state of Delaware, that was formed in 1993. Our equity consists of a 2 percent general partner interest and a 98 percent limited partner interest. Our limited partner interests are represented by our common units, which are listed on the NYSE under the trading symbol “OKS,” and our Class B limited partner units. We are managed under the direction of the Board of Directors of our sole general partner, ONEOK Partners GP. ONEOK Partners GP is a wholly owned subsidiary of ONEOK. ONEOK and its subsidiaries owned a 41.2 percent aggregate equity interest in us at December 31, 2016. Our operations include gathering and processing of natural gas produced from crude oil and natural gas wells. We gather and process natural gas in the Mid-Continent region, which includes the NGL-rich STACK and SCOOP areas in the Anadarko Basin and the Cana-Woodford Shale, Woodford Shale, Springer Shale, Meramec, Granite Wash and Mississippian Lime formations of Oklahoma and Kansas, and the Hugoton and Central Kansas Uplift Basins in Kansas. We also gather and/or process natural gas in two producing basins in the Rocky Mountain region: the Williston Basin, which spans portions of North Dakota and Montana and includes the oil-producing, NGL-rich Bakken Shale and Three Forks formations; and the Powder River Basin located in Wyoming, which includes the NGL-rich Niobrara Shale and Frontier, Turner and Sussex formations in Wyoming. Our natural gas liquids assets consist of facilities that gather, fractionate and treat NGLs and store NGL products primarily in Oklahoma, Kansas, Texas, New Mexico and the Rocky Mountain region where we provide midstream services to producers of NGLs. We own or have an ownership interest in FERC-regulated natural gas liquids gathering and distribution pipelines in Oklahoma, Kansas, Texas, New Mexico, Montana, North Dakota, Wyoming and Colorado, and terminal and storage facilities in Missouri, Nebraska, Iowa and Illinois. We also own FERC-regulated natural gas liquids distribution and refined petroleum products pipelines in Kansas, Missouri, Nebraska, Iowa, Illinois and Indiana that connect our Mid-Continent assets with Midwest markets, including Chicago, Illinois. We own and operate truck- and rail-loading and -unloading facilities that interconnect with our NGL fractionation and pipeline assets. We operate interstate and intrastate natural gas transmission pipelines and natural gas storage facilities. Our FERC-regulated interstate natural gas pipeline assets transport natural gas through pipelines in North Dakota, Minnesota, Wisconsin, Illinois, Indiana, Kentucky, Tennessee, Oklahoma, Texas and New Mexico. Our intrastate natural gas pipeline assets in Oklahoma transport natural gas throughout the state and have access to the major natural gas producing areas in the Mid-Continent region, which include the emerging STACK and SCOOP areas in the Anadarko Basin and the Cana-Woodford Shale, Woodford Shale, Springer Shale, Meramec, Granite Wash and Mississippian Lime formations. The Roadrunner pipeline transports natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas, and is fully subscribed with 25-year firm demand charge, fee-based agreements. We own underground natural gas storage facilities in Oklahoma and Texas that are connected to our intrastate natural gas pipeline assets. We also have underground natural gas storage facilities in Kansas. Consolidation - Our consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. All significant intercompany balances and transactions have been eliminated in consolidation. Investments in unconsolidated affiliates are accounted for using the equity method if we have the ability to exercise significant influence over operating and financial policies of our investee. Under this method, an investment is carried at its acquisition cost and adjusted each period for contributions made, distributions received and our share of the investee’s comprehensive income. For the investments we account for under the equity method, the premium or excess cost over underlying fair value of net assets is referred to as equity-method goodwill. Impairment of equity investments is recorded when the impairments are other than temporary. These amounts are recorded as investments in unconsolidated affiliates on our accompanying Consolidated Balance Sheets. See Note L for disclosures of our unconsolidated affiliates. Distributions paid to us from our unconsolidated affiliates are classified as operating activities on our Consolidated Statements of Cash Flows until the cumulative distributions exceed our proportionate share of income from the unconsolidated affiliate since the date of our initial investment. The amount of cumulative distributions paid to us that exceeds our cumulative proportionate share of income in each period represents a return of investment and is classified as an investing activity on our Consolidated Statements of Cash Flows. Use of Estimates - 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 amount 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. Items that may be estimated include, but are not limited to, the economic useful life of assets, fair value of assets, liabilities and equity-method investments, provisions for uncollectible accounts receivable, unbilled revenues and cost of goods sold, expenses for services received but for which no invoice has been received, the results of litigation and various other recorded or disclosed amounts. We evaluate these estimates on an ongoing basis using historical experience, consultation with experts and other methods we consider reasonable based on the particular circumstances. Nevertheless, actual results may differ significantly from the estimates. Any effects on our financial position or results of operations from revisions to these estimates are recorded in the period when the facts that give rise to the revision become known. Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date. While many of the contracts in our derivative portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive. This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values. For certain transactions, we utilize modeling techniques using NYMEX-settled pricing data and implied forward LIBOR curves. Inputs into our fair value estimates include commodity-exchange prices, over-the-counter quotes, historical correlations of pricing data, data obtained from third-party pricing services and LIBOR and other liquid money-market instrument rates. We validate our valuation inputs with third-party information and settlement prices from other sources, where available. In addition, as prescribed by the income approach, we compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and the LIBOR interest-rate swaps market. We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material. The fair value of our forward-starting interest-rate swaps are determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest-rate swap settlements. Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below: • Level 1 - fair value measurements are based on unadjusted quoted prices for identical securities in active markets, including NYMEX-settled prices. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil. • Level 2 - fair value measurements are based on significant observable pricing inputs, such as NYMEX-settled prices for natural gas and crude oil, and financial models that utilize implied forward LIBOR yield curves for interest-rate swaps. • Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including internally developed natural gas basis and NGL price curves that incorporate observable and unobservable market data from broker quotes, third-party pricing services, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties. We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes. These balances categorized as Level 3 are comprised of derivatives for natural gas and NGLs. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness has not been material. Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety. See Note C for discussion of our fair value measurements. Cash and Cash Equivalents - Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have original maturities of three months or less. Revenue Recognition - Our reportable segments recognize revenue when services are rendered or product is delivered. Our Natural Gas Gathering and Processing segment records revenues when natural gas is gathered or processed through our facilities. Our Natural Gas Liquids segment records revenues based upon contracted services and volumes exchanged or stored under service agreements in the period services are provided. A portion of our revenues for our Natural Gas Pipelines segment and our Natural Gas Liquids segment are recognized based upon contracted capacity and contracted volumes transported and stored under service agreements in the period services are provided. We disaggregate revenue on the Consolidated Statements of Income as follows: • Commodity sales - Commodity sales represent the sale of NGLs, condensate and residue natural gas. We generally purchase a supplier’s raw natural gas or unfractionated NGLs, which we process into marketable commodities and condensate, then we sell these commodities and condensate to downstream customers. Commodity sales are recognized upon delivery or title transfer to the customer, when revenue recognition criteria are met. • Service revenue - Service revenue represents the fees generated from the performance of our services. We enter into a variety of contract types that provide commodity sales and service revenue. We provide services primarily under the following types of contracts: • Fee-based - Under fee-based arrangements, we receive a fee or fees for one or more of the following services: gathering, compression, processing, transmission and storage of natural gas; and gathering, transportation, fractionation and storage of NGLs. The revenue we earn from these arrangements generally is directly related to the volume of natural gas and NGLs that flow through our systems and facilities, and is not normally directly dependent on commodity prices. However, to the extent a sustained decline in commodity prices results in a decline in volumes, our revenues from these arrangements would be reduced. In addition, many of our arrangements provide for fixed fee, minimum volume or firm demand charges. Fee-based arrangements are reported as service revenue on the Consolidated Statements of Income. • Percent-of-proceeds - Under POP arrangements in our Natural Gas Gathering and Processing segment, we generally purchase the producer’s raw natural gas which we process into natural gas and natural gas liquids, then we sell these commodities and condensate to downstream customers. We remit sales proceeds to the producer according to the contractual terms and retain our portion. Typically, our POP arrangements also include a fee-based component. In many cases, our Natural Gas Gathering and Processing segment provides services under contracts that contain a combination of the arrangements described above. When services are provided (in addition to raw natural gas purchased) under POP with fee contracts, we record such fees as service revenue on the Consolidated Statements of Income. The terms of our contracts vary based on natural gas quality conditions, the competitive environment when the contracts are signed and customer requirements. Cost of Sales and Fuel - Cost of sales and fuel primarily includes (i) the cost of purchased commodities, including NGLs, natural gas and condensate, (ii) fees incurred for third-party transportation, fractionation and storage of commodities, and (iii) fuel and power costs incurred to operate our own facilities that gather, process, transport and store commodities. Operations and Maintenance - Operations and maintenance primarily includes (i) payroll and benefit costs, (ii) third-party costs for operations, maintenance and integrity management, regulatory compliance and environmental and safety, and (iii) other business related service costs. Accounts Receivable - Accounts receivable represent valid claims against nonaffiliated customers for products sold or services rendered, net of allowances for doubtful accounts. We assess the creditworthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. Outstanding customer receivables are reviewed regularly for possible nonpayment indicators, and allowances for doubtful accounts are recorded based upon management’s estimate of collectability at each balance sheet date. At December 31, 2016 and 2015 , our allowance for doubtful accounts was not material. Inventory - The values of current natural gas and NGLs in storage are determined using the lower of weighted-average cost or market method. Noncurrent natural gas and NGLs are classified as property and valued at cost. Materials and supplies are valued at average cost. Commodity Imbalances - Commodity imbalances represent amounts payable or receivable for NGL exchange contracts and natural gas pipeline imbalances and are valued at market prices. Under the majority of our NGL exchange agreements, we physically receive volumes of unfractionated NGLs, including the risk of loss and legal title to such volumes, from the exchange counterparty. In turn, we deliver NGL products back to the customer and charge them gathering, fractionation and transportation fees. To the extent that the volumes we receive under such agreements differ from those we deliver, we record a net exchange receivable or payable position with the counterparties. These net exchange receivables and payables are settled with movements of NGL products rather than with cash. Natural gas pipeline imbalances are settled in cash or in-kind, subject to the terms of the pipelines’ tariffs or by agreement. Derivatives and Risk Management - We utilize derivatives to reduce our market-risk exposure to commodity price and interest-rate fluctuations and to achieve more predictable cash flows. We record all derivative instruments at fair value, with the exception of normal purchases and normal sales transactions that are expected to result in physical delivery. Commodity price and interest-rate volatility may have a significant impact on the fair value of derivative instruments as of a given date. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it. The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements: Recognition and Measurement Accounting Treatment Balance Sheet Income Statement Normal purchases and normal sales - Fair value not recorded - Change in fair value not recognized in earnings Mark-to-market - Recorded at fair value - Change in fair value recognized in earnings Cash flow hedge - Recorded at fair value - Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings - Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) - Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated other comprehensive income (loss) into earnings when the forecasted transaction affects earnings Fair value hedge - Recorded at fair value - The gain or loss on the derivative instrument is recognized in earnings - Change in fair value of the hedged item is recorded as an adjustment to book value - Change in fair value of the hedged item is recognized in earnings To reduce our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter into futures, forward purchases and sales, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate. Interest-rate swaps are used from time to time to manage interest-rate risk. Under certain conditions, we designate our derivative instruments as a hedge of exposure to changes in fair values or cash flows. We formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. We specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. We also document our normal purchases and normal sales transactions that we expect to result in physical delivery and that we elect to exempt from derivative accounting treatment. The realized revenues and purchase costs of our derivative instruments not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis. Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows. See Notes C and D for more discussion of our fair value measurements and risk-management and hedging activities using derivatives. Property, Plant and Equipment - Our properties are stated at cost, including AFUDC and capitalized interest. In some cases, the cost of regulated property retired or sold, plus removal costs, less salvage, is charged to accumulated depreciation. Gains and losses from sales or transfers of nonregulated properties or an entire operating unit or system of our regulated properties are recognized in income. Maintenance and repairs are charged directly to expense. The interest portion of AFUDC and capitalized interest represent the cost of borrowed funds used to finance construction activities for regulated and nonregulated projects, respectively. We capitalize interest costs during the construction or upgrade of qualifying assets. These costs are recorded as a reduction to interest expense. The equity portion of AFUDC represents the capitalization of the estimated average cost of equity used during the construction of major projects and is recorded in the cost of our regulated properties and as a credit to the allowance for equity funds used during construction. Our properties are depreciated using the straight-line method over their estimated useful lives. Generally, we apply composite depreciation rates to functional groups of property having similar economic circumstances. We periodically conduct depreciation studies to assess the economic lives of our assets. For our regulated assets, these depreciation studies are completed as a part of our rate proceedings or tariff filings, and the changes in economic lives, if applicable, are implemented prospectively when the new rates are billed. For our nonregulated assets, if it is determined that the estimated economic life changes, the changes are made prospectively. Changes in the estimated economic lives of our property, plant and equipment could have a material effect on our financial position or results of operations. Property, plant and equipment on our Consolidated Balance Sheets includes construction work in process for capital projects that have not yet been placed in service and therefore are not being depreciated. Assets are transferred out of construction work in process when they are substantially complete and ready for their intended use. See Note E for disclosures of our property, plant and equipment. Impairment of Goodwill and Long-Lived Assets, Including Intangible Assets - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. As the commodity price environment has remained relatively low since 2015, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates. Our goodwill impairment analysis performed as of July 1, 2016, did not result in an impairment charge nor did our analysis reflect any reporting units at risk. In each reporting unit, the fair value substantially exceeded the carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of our reporting units is less than the carrying value of its net assets. As part of our impairment test, we may first assess qualitative factors (including macroeconomic conditions, industry and market considerations, cost factors and overall financial performance) to determine whether it is more likely than not that the fair value of each of our reporting units is less than its carrying amount. If further testing is necessary or a quantitative test is elected, we perform a two-step impairment test for goodwill. In the first step, an initial assessment is made by comparing the fair value of a reporting unit with its book value, including goodwill. If the fair value is less than the book value, an impairment is indicated, and we must perform a second test to measure the amount of the impairment. In the second test, we calculate the implied fair value of the goodwill by deducting the fair value of all tangible and intangible net assets of the reporting unit from the fair value determined in step one of the assessment. If the carrying value of the goodwill exceeds the implied fair value of the goodwill, we will record an impairment charge. 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. We assess our long-lived assets, including intangible assets with finite useful lives, 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. For the investments we account for under the equity method, the impairment test 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 reevaluate the amount at which we carry our equity-method investments to determine whether current events or circumstances warrant adjustments to our carrying values. See Notes E , F and L for our long-lived assets, goodwill and intangible assets and investments in unconsolidated affiliates disclosures. Regulation - Our intrastate natural gas transmission and natural gas liquids pipelines are subject to the rate regulation and accounting requirements of the OCC, KCC, RRC and various municipalities in Texas. Our interstate natural gas and natural gas liquids pipelines are subject to regulation by the FERC. In Kansas and Texas, natural gas storage may be regulated by the state and the FERC for certain types of services. Accordingly, portions of our Natural Gas Liquids and Natural Gas Pipelines segments follow the accounting and reporting guidance for regulated operations. In our Consolidated Financial Statements and our Notes to Consolidated Financial Statements, regulated operations are defined pursuant to Financial Accounting Standards Board’s (FASB) Accounting Standards Codification (ASC) 980, Regulated Operations. During the rate-making process for certain of our assets, regulatory authorities set the framework for what we can charge customers for our services and establish the manner that our costs are accounted for, including allowing us to defer recognition of certain costs and permitting recovery of the amounts through rates over time as opposed to expensing such costs as incurred. Certain examples of types of regulatory guidance include costs for fuel and losses, acquisition costs, contributions in aid of construction, charges for depreciation, and gains or losses on disposition of assets. This allows us to stabilize rates over time rather than passing such costs on to the customer for immediate recovery. Actions by regulatory authorities could have an effect on the amount recovered from rate payers. Any difference in the amount recoverable and the amount deferred is recorded as income or expense at the time of the regulatory action. A write-off of regulatory assets and costs not recovered may be required if all or a portion of the regulated operations have rates that are no longer: • established by independent, third-party regulators; • designed to recover the specific entity’s costs of providing regulated services; and • set at levels that will recover our costs when considering the demand and competition for our services. At December 31, 2016 and 2015 , we recorded regulatory assets of approximately $5.5 million and $5.8 million , respectively, which are currently being recovered and are expected to be recovered from our customers. Regulatory assets are being recovered as a result of approved rate proceedings over varying time periods up to 50 years. These assets are reflected in other assets on our Consolidated Balance Sheets. Income Taxes - We are not a taxable entity for federal income tax purposes. As such, we do not directly pay federal income tax. For our operations in Texas, we are subject to the Texas franchise tax, which is included in income tax expense in our consolidated statements of income. Our taxable income or loss, which may vary substantially from the net income or loss reported in our Consolidated Statements of Income, is included in the federal income tax returns of each partner. The aggregate difference in the basis of our net assets for financial and income tax purposes cannot be readily determined, as we do not have access to all information about each partner’s tax attributes related to us. Our corporate subsidiaries are required to pay federal and state income taxes. Deferred income taxes are provided for the difference between the financial statement and income tax basis of assets and liabilities and carryforward items based on income tax laws and rates existing at the time the temporary differences are expected to reverse. Generally, the effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date of the rate change. For regulated companies, the effect on deferred tax assets and liabilities of a change in tax rates is recorded as regulatory assets and regulatory liabilities in the period that includes the enactment date, if, as a result of an action by a regulator, it is probable that the effect of the change in tax rates will be recovered from or returned to customers through future rates. We utilize a more-likely-than-not recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position that is taken or expected to be taken in a tax return. We reflect penalties and interest as part of income tax expense as they become applicable for tax provisions that do not meet the more-likely-than-not recognition threshold and measurement attribute. During 2016, 2015 and 2014 , our tax positions did not require an establishment of a material reserve. We file numerous consolidated and separate income tax returns with federal tax authorities of the United States along with the tax authorit

ONEOK PARTNERS ACQUISITION (Not

ONEOK PARTNERS ACQUISITION (Notes)	12 Months Ended
	Dec. 31, 2016
Subsequent Event [Line Items]
Subsequent Events [Text Block]	ACQUISITION OF ONEOK PARTNERS On January 31, 2017, we and ONEOK entered into the Merger Agreement in which ONEOK will acquire all of our outstanding common units representing limited partner interests in us not already directly or indirectly owned by ONEOK in an all stock-for-unit transaction at a ratio of 0.985 of ONEOK common shares per common unit of ONEOK Partners, in a taxable transaction to our common unitholders. Following completion of the Merger Transaction, all of our outstanding common units will be owned by ONEOK and will no longer be publicly traded. All of our outstanding debt is expected to remain outstanding. We and ONEOK expect to enter into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees and becomes liable for the indebtedness of each other party to the agreement. A Special Committee of the Board of Directors of ONEOK, the Conflicts Committee of the Board of Directors of our general partner and the Board of Directors of our general partner each unanimously approved the Merger Agreement. Subject to customary approvals and conditions, the Merger Transaction is expected to close in the second quarter of 2017. The Merger Transaction is subject to the approval of our common unitholders and the approval by ONEOK shareholders of the issuance of ONEOK common shares in the Merger Transaction. The Merger Agreement contains certain termination rights, including the right for either us or ONEOK, as applicable, to terminate the Merger Agreement if the closing of the transactions contemplated by the Merger Agreement has not occurred on or before September 30, 2017. In the event of termination of the Merger Agreement under certain circumstances, we may be required to pay ONEOK a termination fee of (up to, in certain instances, $300 million in cash) and, under other certain circumstances, ONEOK may be required to pay us a termination fee in the form of a temporary reduction in incentive distributions (up to, in certain instances, $300 million).

FAIR VALUE MEASUREMENTS (Notes)

FAIR VALUE MEASUREMENTS (Notes)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS Recurring Fair Value Measurements - The following tables set forth our recurring fair value measurements for the periods indicated: December 31, 2016 Level 1 Level 2 Level 3 Total - Gross Netting (a) Total - Net (b) ( Thousands of dollars ) Derivative assets Commodity contracts Financial contracts $ 1,147 $ — $ 4,564 $ 5,711 $ (4,760 ) $ 951 Interest-rate contracts — 47,457 — 47,457 — 47,457 Total derivative assets $ 1,147 $ 47,457 $ 4,564 $ 53,168 $ (4,760 ) $ 48,408 Derivative liabilities Commodity contracts Financial contracts $ (31,458 ) $ — $ (24,861 ) $ (56,319 ) $ 56,319 $ — Physical contracts — — (3,022 ) (3,022 ) — (3,022 ) Interest-rate contracts — (12,795 ) — (12,795 ) — (12,795 ) Total derivative liabilities $ (31,458 ) $ (12,795 ) $ (27,883 ) $ (72,136 ) $ 56,319 $ (15,817 ) (a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2016 , we held no cash and posted $67.7 million of cash with various counterparties, including $51.6 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $16.1 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets. (b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets. December 31, 2015 Level 1 Level 2 Level 3 Total - Gross Netting (a) Total - Net (b) ( Thousands of dollars ) Derivative assets Commodity contracts Financial contracts $ 38,921 $ — $ 7,253 $ 46,174 $ (42,414 ) $ 3,760 Physical contracts — — 3,591 3,591 — 3,591 Total derivative assets $ 38,921 $ — $ 10,844 $ 49,765 $ (42,414 ) $ 7,351 Derivative liabilities Commodity contracts Financial contracts $ (4,513 ) $ — $ (3,513 ) $ (8,026 ) $ 8,026 $ — Interest-rate contracts — (9,936 ) — (9,936 ) — (9,936 ) Total derivative liabilities $ (4,513 ) $ (9,936 ) $ (3,513 ) $ (17,962 ) $ 8,026 $ (9,936 ) (a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2015 , we held $34.4 million of cash from various counterparties that is offsetting derivative net asset positions in the table above under master-netting arrangements and had no cash collateral posted. (b) - Included in other current assets or other current liabilities in our Consolidated Balance Sheets. The following table sets forth a reconciliation of our Level 3 fair value measurements for the periods indicated: Years Ended December 31, Derivative Assets (Liabilities) 2016 2015 ( Thousands of dollars ) Net assets (liabilities) at beginning of period $ 7,331 $ 9,285 Total realized/unrealized gains (losses): Included in earnings (a) (320 ) 216 Included in other comprehensive income (loss) (30,330 ) (2,170 ) Net assets (liabilities) at end of period $ (23,319 ) $ 7,331 (a) - Included in commodity sales revenues in our Consolidated Statements of Income. Realized/unrealized gains (losses) include the realization of our derivative contracts through maturity. During the years ended December 31, 2016 and 2015 , gains or losses included in earnings attributable to the change in unrealized gains or losses relating to assets and liabilities still held at the end of each reporting period were not material. We recognize transfers into and out of the levels in the fair value hierarc hy as of the end of each reporting period. During the years ended December 31, 2016 and 2015 , there were no transfers between levels. Other Financial Instruments - The approximate fair value of cash and cash equivalents, accounts receivable, accounts payable and short-term borrowings is equal to book value, due to the short-term nature of these items. Our cash and cash equivalents are comprised of bank and money market accounts and are classified as Level 1. Our short-term borrowings are classified as Level 2 since the estimated fair value of the short-term borrowings can be determined using information available in the commercial paper market. The estimated fair value of the aggregate of our senior notes outstanding, including current maturities, was $7.1 billion and $6.2 billion at December 31, 2016 and 2015 , respectively. The book value of the aggregate of our senior notes outstanding, including current maturities, was $6.7 billion and $6.8 billion at December 31, 2016 and 2015 , respectively. The estimated fair value of the aggregate of our senior notes outstanding was determined using quoted market prices for similar issues with similar terms and maturities. The estimated fair value of our long-term debt is classified as Level 2. During 2015 and 2014, we recorded noncash impairment charges primarily related to our equity investments in the dry natural gas area of the Powder River Basin. The valuation of these investments required use of significant unobservable inputs. We used an income approach to estimate the fair value of our investments. Our discounted cash flow analysis included the following inputs that are not readily available: a discount rate reflective of our cost of capital and estimated contract rates, volumes, operating and maintenance costs and capital expenditures. The estimated fair value of these investments is classified as Level 3. See Note L for additional information about our equity investments and the impairment charges.

RISK MANAGEMENT AND HEDGING ACT

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Notes)	12 Months Ended
	Dec. 31, 2016
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 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. We are also subject to the risk of interest-rate fluctuation in the normal course of business. Commodity price risk - Commodity price risk refers to the risk of loss in cash flows and future earnings arising from adverse changes in the price of natural gas, NGLs and condensate. We use the following commodity derivative instruments to mitigate the near-term commodity price risk associated with a portion of the forecasted sales of these commodities: • Futures contracts - Standardized contracts to purchase or sell natural gas and crude oil for future delivery or settlement under the provisions of exchange regulations; • Forward contracts - Nonstandardized commitments between two parties to purchase or sell natural gas, crude oil or NGLs for future physical delivery. These contracts are typically nontransferable and can only be canceled with the consent of both parties; • Swaps - Exchange of one or more payments based on the value of one or more commodities. These instruments transfer the financial risk associated with a future change in value between the counterparties of the transaction, without also conveying ownership interest in the asset or liability; and • Options - Contractual agreements that give the holder the right, but not the obligation, to buy or sell a fixed quantity of a commodity at a fixed price within a specified period of time. Options may either be standardized and exchange-traded or customized and nonexchange-traded. We may also use other instruments including collars to mitigate commodity price risk. A collar is a combination of a purchased put option and a sold call option, which places a floor and a ceiling price for commodity sales being hedged. 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 fee revenues may increase or decrease if production volumes, delivery pressures or commodity prices change relative to specified thresholds. We also are exposed to basis risk between the various production and market locations where we receive 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 exposed to location price differential risk, primarily as a result of the relative value of NGL purchases at one location and sales at another location. We are also exposed to commodity price risk resulting from the relative values of the various NGL products to each other, NGLs in storage and the relative value of NGLs to natural gas. We utilize physical-forward contracts and commodity derivative financial instruments to reduce the impact of price fluctuations related to NGLs. In our Natural Gas Pipelines segment, we are exposed to commodity price risk because our intrastate and interstate natural gas pipelines retain natural gas from our customers for operations or as part of our fee for services provided. When the amount of natural gas consumed in operations by these pipelines differs from the amount provided by our customers, our pipelines must buy or sell natural gas, or store or use natural gas from inventory, which can expose us 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 price fluctuations related to natural gas. At December 31, 2016 and 2015 , 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 January 2016, we entered into forward-starting interest-rate swaps with notional amounts totaling $1 billion to hedge the variability of our LIBOR-based interest payments, all of which were active swaps as of December 31, 2016. In addition, in June 2016, we entered into forward-starting interest rate swaps with notional amounts totaling $750 million to hedge the variability of interest payments on a portion of our forecasted debt issuances that may result from changes in the benchmark interest rate before the debt is issued, resulting in total notional amounts of this type of interest-rate swap of $ 1.2 billion at December 31, 2016, compared with $400 million at December 31, 2015. All of our interest-rate swaps are designated as cash flow hedges. Upon our debt issuance in March 2015, we settled $500 million of our interest-rate swaps and realized a loss of $55.1 million , which is included in accumulated other comprehensive loss and will be amortized to interest expense over the term of the related debt. Fair Values of Derivative Instruments - The following table sets forth the fair values of our derivative instruments presented on a gross basis for the periods indicated: December 31, 2016 December 31, 2015 Location in our Consolidated Balance Sheets Assets (Liabilities) Assets (Liabilities) ( Thousands of dollars ) Derivatives designated as hedging instruments Commodity contracts Financial contracts Other current assets/other current liabilities $ 1,155 $ (49,938 ) $ 39,255 $ (1,440 ) Other assets/deferred credits and other liabilities 210 (2,142 ) — — Physical contracts Other current assets/other current liabilities — (3,022 ) 3,591 — Interest-rate contracts Other assets/other current liabilities 47,457 (12,795 ) — (9,936 ) Total derivatives designated as hedging instruments 48,822 (67,897 ) 42,846 (11,376 ) Derivatives not designated as hedging instruments Commodity contracts Financial contracts Other current assets/other current liabilities 4,346 (4,239 ) 6,919 (6,586 ) Total derivatives not designated as hedging instruments 4,346 (4,239 ) 6,919 (6,586 ) Total derivatives $ 53,168 $ (72,136 ) $ 49,765 $ (17,962 ) Notional Quantities for Derivative Instruments - The following table sets forth the notional quantities for derivative instruments held for the periods indicated: December 31, 2016 December 31, 2015 Contract Type Purchased/ Payor Sold/ Receiver Purchased/ Payor Sold/ Receiver Derivatives designated as hedging instruments: Cash flow hedges Fixed price -Natural gas ( Bcf ) Futures and swaps — (38.4 ) — (27.1 ) -Natural gas ( Bcf ) Put options 49.5 — — — -Crude oil and NGLs ( MMBbl ) Futures, forwards and swaps — (3.6 ) — (2.3 ) Basis -Natural gas ( Bcf ) Futures and swaps — (38.4 ) — (27.1 ) Interest-rate contracts ( Millions of dollars ) Swaps $ 2,150.0 $ — $ 400.0 $ — Derivatives not designated as hedging instruments: Fixed price -Natural gas ( Bcf ) Futures and swaps 0.4 — — — -NGLs ( MMBbl ) Futures, forwards and swaps 0.5 (0.7 ) 0.6 (0.6 ) Basis -Natural gas ( Bcf ) Futures and swaps 0.4 — — — These notional amounts are used to summarize the volume of financial instruments; however, they do not reflect the extent to which the positions offset one another and consequently do not reflect our actual exposure to market or credit risk. Cash Flow Hedges - At December 31, 2016 , our Consolidated Balance Sheet reflected a net loss of $161.5 million in accumulated other comprehensive loss. The portion of accumulated other comprehensive loss attributable to our commodity derivative financial instruments is an unrealized loss of $63.4 million , which will be realized within the next 24 months as the forecasted transactions affect earnings. If commodity prices remain at the current levels, we will realize approximately $61.5 million in net losses over the next 12 months and approximately $1.9 million in net losses thereafter. The amount deferred in accumulated other comprehensive loss attributable to our settled interest-rate swaps is a loss of $125.9 million , which will be recognized over the life of the long-term, fixed-rate debt, including losses of $16.6 million that will be reclassified into earnings during the next 12 months as the hedged items affect earnings. The remaining amounts in accumulated other comprehensive loss are attributable primarily to forward-starting interest-rate swaps with future settlement dates, which will be amortized to interest expense over the life of long-term, fixed-rate debt upon issuance of the debt. The following table sets forth the unrealized effect of cash flow hedges recognized in other comprehensive income (loss) for the periods indicated: Derivatives in Cash Flow Hedging Relationships Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Commodity contracts $ (78,513 ) $ 70,065 $ 32,354 Interest-rate contracts 42,761 (22,565 ) (96,993 ) Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion) $ (35,752 ) $ 47,500 $ (64,639 ) The following table sets forth the effect of cash flow hedges in our Consolidated Statements of Income for the periods indicated: Derivatives in Cash Flow Hedging Relationships Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income (Effective Portion) Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Commodity contracts Commodity sales revenues $ 26,422 $ 81,089 $ (21,052 ) Interest-rate contracts Interest expense (15,705 ) (14,055 ) (10,601 ) Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion) $ 10,717 $ 67,034 $ (31,653 ) Credit Risk - We monitor the creditworthiness of our counterparties and compliance with policies and limits established by our Risk Oversight and Strategy Committee. We maintain credit policies with regard to our counterparties that we believe minimize overall credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit ratings, bond yields and credit default swap rates), collateral requirements under certain circumstances and the use of standardized master-netting agreements that allow us to net the positive and negative exposures associated with a single counterparty. We have counterparties whose credit is not rated, and for those customers, we use internally developed credit ratings. From time to time, 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 as of December 31, 2016 . The counterparties to our derivative contracts consist primarily of major energy companies, financial institutions and commercial and industrial end users. This concentration of counterparties may affect our overall exposure to credit risk, either positively or negatively, in that the counterparties may be affected similarly by changes in economic, regulatory or other conditions. Based on our policies, exposures, credit and other reserves, we do not anticipate a material adverse effect on our financial position or results of operations as a result of counterparty nonperformance. At December 31, 2016 , the net credit exposure from our derivative assets is primarily with investment-grade companies in the financial services sector.

PROPERTY, PLANT AND EQUIPMENT (

PROPERTY, PLANT AND EQUIPMENT (Notes)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT The following table sets forth our property, plant and equipment by property type, for the periods indicated: Estimated Useful Lives (Years) December 31, December 31, ( Thousands of dollars ) Nonregulated Gathering pipelines and related equipment 5 to 40 $ 3,352,963 $ 2,961,388 Processing and fractionation and related equipment 3 to 40 3,831,966 3,627,062 Storage and related equipment 5 to 54 558,695 510,820 Transmission pipelines and related equipment 5 to 54 689,804 598,375 General plant and other 2 to 60 264,049 226,858 Construction work in process — 371,337 690,179 Regulated Storage and related equipment 5 to 25 13,524 22,085 Natural gas transmission pipelines and related equipment 5 to 77 1,345,740 1,325,235 Natural gas liquids transmission pipelines and related equipment 5 to 88 4,309,341 4,208,121 General plant and other 2 to 50 54,643 53,962 Construction work in process — 62,634 83,461 Property, plant and equipment 14,854,696 14,307,546 Accumulated depreciation and amortization - nonregulated (1,526,400 ) (1,290,931 ) Accumulated depreciation and amortization - regulated (865,604 ) (759,824 ) Net property, plant and equipment $ 12,462,692 $ 12,256,791 The average depreciation rates for our regulated property are set forth, by segment, in the following table for the periods indicated: Years Ended December 31, 2016 2015 2014 Natural Gas Liquids 1.9% 1.9% 2.0% Natural Gas Pipelines 2.1% 2.1% 2.1% We incurred costs for construction work in process that had not been paid at December 31, 2016, 2015 and 2014 , of $83.0 million , $115.7 million and $187.2 million , respectively. Such amounts are not included in capital expenditures (less AFUDC and capitalized interest) on the Consolidated Statements of Cash Flows. Impairment Charges - Due to the continued and greater than expected decline in volumes gathered in the dry natural gas area of the Powder River Basin, we evaluated our long-lived assets and equity investments in this area in 2015 and made the decision to cease operations of our wholly owned coal-bed methane natural gas gathering system in 2016. This resulted in a $63.5 million noncash impairment charge to long-lived assets in 2015 in our Natural Gas Gathering and Processing segment. In addition, we recorded noncash impairment charges of approximately $20.2 million for previously idled assets in the Natural Gas Gathering and Processing and Natural Gas Liquids segments in 2015, as our expectation for future use of these assets changed.

GOODWILL AND INTANGIBLE ASSETS

GOODWILL AND INTANGIBLE ASSETS (Notes)	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
GOODWILL AND INTANGIBLE ASSETS	GOODWILL AND INTANGIBLE ASSETS Goodwill - The following table sets forth our goodwill, by segment, for the periods indicated: December 31, 2016 December 31, 2015 ( Thousands of dollars ) Natural Gas Gathering and Processing $ 112,141 $ 112,141 Natural Gas Liquids 247,566 247,566 Natural Gas Pipelines 129,011 129,011 Total goodwill $ 488,718 $ 488,718 Intangible Assets - Our intangible assets relate primarily to contracts acquired through acquisitions in our Natural Gas Gathering and Processing and Natural Gas Liquids segments, which are being amortized over periods of 20 to 40 years. Amortization expense for intangible assets for 2016, 2015 and 2014 was $11.9 million , $11.9 million and $11.8 million , respectively, and the aggregate amortization expense for each of the next five years is estimated to be approximately $11.9 million. The following table reflects the gross carrying amount and accumulated amortization of intangible assets for the periods presented: December 31, December 31, ( Thousands of dollars ) Gross intangible assets $ 426,068 $ 426,068 Accumulated amortization (101,809 ) (89,909 ) Net intangible assets $ 324,259 $ 336,159

DEBT (Notes)

DEBT (Notes)	12 Months Ended
	Dec. 31, 2016
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	DEBT The following table sets forth our debt for the periods indicated: December 31, December 31, ( Thousands of dollars ) ONEOK Partners Borrowings outstanding under the Partnership Credit Agreement at 1.60% as of December 31, 2015 (a) $ — $ 300,000 Commercial paper outstanding, bearing a weighted-average interest rate of 1.27% and 1.23%, respectively 1,110,277 246,340 Senior unsecured obligations: $650,000 at 3.25% due 2016 — 650,000 $450,000 at 6.15% due 2016 — 450,000 $400,000 at 2.0% due 2017 400,000 400,000 $425,000 at 3.2% due 2018 425,000 425,000 $1,000,000 term loan, variable rate, due 2019 1,000,000 — $500,000 at 8.625% due 2019 500,000 500,000 $300,000 at 3.8% due 2020 300,000 300,000 $900,000 at 3.375 % due 2022 900,000 900,000 $425,000 at 5.0 % due 2023 425,000 425,000 $500,000 at 4.9 % due 2025 500,000 500,000 $600,000 at 6.65% due 2036 600,000 600,000 $600,000 at 6.85% due 2037 600,000 600,000 $650,000 at 6.125% due 2041 650,000 650,000 $400,000 at 6.2% due 2043 400,000 400,000 Guardian Pipeline Average 7.88% due 2022 44,257 51,907 Total debt 7,854,534 7,398,247 Unamortized debt issuance costs and discounts (45,300 ) (48,945 ) Current maturities of long-term debt (407,650 ) (107,650 ) Short-term borrowings (b) (1,110,277 ) (546,340 ) Long-term debt $ 6,291,307 $ 6,695,312 (a) - We had $14 million of letters of credit issued at December 31, 2016 and 2015. (b) - Individual issuances of commercial paper under our $2.4 billion commercial paper program generally mature in 90 days or less. However, these issuances are supported by and reduce the borrowing capacity under our Partnership Credit Agreement. Partnership Credit Agreement - In January 2016, we extended the term of our Partnership Credit Agreement by one year to January 2020. Our Partnership Credit Agreement is a $2.4 billion revolving credit facility and includes a $100 million sublimit for the issuance of standby letters of credit and a $150 million swingline sublimit. Our Partnership Credit Agreement is available for general partnership purposes and had available capacity of approximately $1.3 billion at December 31, 2016. Our Partnership Credit Agreement contains provisions for an applicable margin rate and an annual facility fee, both of which adjust with changes in our credit rating. Under the terms of the Partnership Credit Agreement, based on our current credit ratings, borrowings, if any, will accrue interest at LIBOR plus 117.5 basis points , and the annual facility fee is 20 basis points. Our Partnership Credit Agreement is guaranteed fully and unconditionally by the Intermediate Partnership. Borrowings under our Partnership Credit Agreement are nonrecourse to ONEOK. Following the completion of the Merger Transaction described in Note B , we and ONEOK expect to enter into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees and becomes liable for the indebtedness of each other party to the agreement. Our Partnership Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA, as defined in our Partnership Credit Agreement, adjusted for all noncash charges and increased for projected EBITDA from certain lender-approved capital expansion projects) of no more than 5.0 to 1. If we consummate one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will increase to 5.5 to 1 for the quarter in which the acquisition was completed and the two following quarters. If we were to breach certain covenants in our Partnership Credit Agreement, amounts outstanding under our Partnership Credit Agreement, if any, may become due and payable immediately. At December 31, 2016 , our ratio of indebtedness to adjusted EBITDA was 4.1 to 1, and we were in compliance with all covenants under our Partnership Credit Agreement. Senior Unsecured Obligations - All notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness, and are structurally subordinate to any of the existing and future debt and other liabilities of any nonguarantor subsidiaries. Issuances and maturities - In January 2016, we entered into the $1.0 billion senior unsecured Term Loan Agreement with a syndicate of banks. The Term Loan Agreement matures in January 2019 and bears interest at LIBOR plus 130 basis points based on our current credit ratings. At December 31, 2016, the interest rate was 2.04 percent . The Term Loan Agreement contains an option, which may be exercised up to two times, to extend the term of the loan, in each case, for an additional one-year term, subject to approval of the banks. The Term Loan Agreement allows prepayment of all or any portion outstanding without penalty or premium. During the first quarter 2016, we drew the full $ 1.0 billion available under the agreement and used the proceeds to repay $650 million of senior notes at maturity, to repay amounts outstanding under our commercial paper program and for general partnership purposes. We repaid our $450 million , 6.15 percent senior notes at maturity in October 2016, with a combination of cash on hand and short-term borrowings. In March 2015, we completed an underwritten public offering of $800 million of senior notes, consisting of $300 million , 3.8 percent senior notes due 2020, and $500 million , 4.9 percent senior notes due 2025. The net proceeds, after deducting underwriting discounts, commissions and offering expenses, were approximately $792.3 million . We used the proceeds to repay amounts outstanding under our commercial paper program and for general partnership purposes. The aggregate maturities of long-term debt outstanding as of December 31, 2016, for the years 2017 through 2021 are shown below: ONEOK Partners Guardian Pipeline Total ( Millions of dollars ) 2017 $ 400.0 $ 7.7 $ 407.7 2018 $ 425.0 $ 7.7 $ 432.7 2019 $ 1,500.0 $ 7.7 $ 1,507.7 2020 $ 300.0 $ 7.7 $ 307.7 2021 $ — $ 7.7 $ 7.7 Covenants - Our Term Loan Agreement contains substantially the same covenants as our Partnership Credit Agreement. Our senior notes are governed by an indenture, dated as of September 25, 2006, between us and Wells Fargo Bank, N.A., the trustee, as supplemented. The indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series. The indenture contains covenants including, among other provisions, limitations on our ability to place liens on our property or assets and to sell and lease back our property. The indenture includes an event of default upon acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of any of our outstanding senior notes to declare those notes immediately due and payable in full . We may redeem our senior notes due 2019, 2036 and 2037, in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. We may redeem our senior notes due 2017 and our senior notes due 2022 at par starting one month and three months, respectively, before their maturity dates. We may redeem our senior notes due 2041 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting six months before its maturity date. Prior to that date, we may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. We may redeem our senior notes due 2018, 2020, 2023, 2025, and 2043 at par, plus accrued and unpaid interest to the redemption date, starting one month, one month, three months, three months, and six months, respectively, before their maturity dates. Prior to these dates, we may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. ONEOK Partners Debt Guarantee - Our senior notes are guaranteed fully and unconditionally on a senior unsecured basis by the Intermediate Partnership. The guarantee ranks equally in right of payment to all of the Intermediate Partnership’s existing and future unsecured senior indebtedness. See Note R for additional information on the guarantee. Our long-term debt is nonrecourse to our general partner. Neither we nor ONEOK guarantees the debt or other similar commitments of unaffiliated parties. ONEOK does not guarantee the debt, commercial paper borrowings under the Partnership Credit Agreement or other similar commitments of ONEOK Partners, and ONEOK Partners does not guarantee the debt or other similar commitments of ONEOK. Following the completion of the Merger Transaction, we and ONEOK expect to enter into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees and becomes liable for the indebtedness of each other party to the agreement. Guardian Pipeline Senior Notes - These senior notes were issued under a master shelf agreement dated November 8, 2001, with certain financial institutions. Principal payments are due quarterly through 2022. Guardian Pipeline’s senior notes contain financial covenants that require the maintenance of certain financial ratios as defined in the master shelf agreement based on Guardian Pipeline’s financial position and results of operations. Upon any breach of these covenants, all amounts outstanding under the master shelf agreement may become due and payable immediately . At December 31, 2016, Guardian Pipeline was in compliance with its financial covenants . Other - We amortize premiums, discounts and expenses incurred in connection with the issuance of long-term debt consistent with the terms of the respective debt instrument.

EQUITY (Notes)

EQUITY (Notes)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
EQUITY	EQUITY ONEOK - ONEOK and its affiliates owned all of the Class B units, 41.3 million common units and the entire 2 percent general partner interest in us, which together constituted a 41.2 percent ownership interest in us at December 31, 2016 . Equity Issuances - We have an “at-the-market” equity program for the offer and sale from time to time of our common units, up to an aggregate amount of $650 million . The program allows us to offer and sell our common units at prices we deem appropriate through a sales agent. Sales of common units are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common units under the program. At December 31, 2016 , we had approximately $138 million of registered common units available for issuance through our “at-the-market” equity program. During the year ended December 31, 2016 , we sold no common units through our “at-the-market” equity program. In August 2015, we completed a private placement of 21.5 million common units at a price of $30.17 per unit with ONEOK. Additionally, we completed a concurrent sale of approximately 3.3 million common units at a price of $30.17 per unit to funds managed by Kayne Anderson Capital Advisors in a registered direct offering, which were issued through our existing “at-the-market” equity program. The combined offerings generated net cash proceeds of approximately $749 million . In conjunction with these issuances, ONEOK Partners GP contributed approximately $15.3 million in order to maintain its 2 percent general partner interest in us. We used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings. During the year ended December 31, 2015 , we sold 10.5 million common units through our “at-the-market” equity program, including the units sold to funds managed by Kayne Anderson Capital Advisors in the offering discussed above. The net proceeds, including ONEOK Partners GP’s contribution to maintain its 2 percent general partner interest in us, were approximately $381.6 million , which were used for general partnership purposes, including repayment of commercial paper borrowings. In May 2014, we completed an underwritten public offering of 13.9 million common units at a public offering price of $52.94 per common unit, generating net proceeds of approximately $714.5 million . In conjunction with this issuance, ONEOK Partners GP contributed approximately $15.0 million in order to maintain its 2 percent general partner interest in us. We used the proceeds for general partnership purposes, including capital expenditures and repayment of commercial paper borrowings. During the year ended December 31, 2014, we sold 7.9 million common units through our “at-the-market” equity program. The net proceeds, including ONEOK Partners GP’s contribution to maintain its 2 percent general partner interest in us, were approximately $402.1 million , which were used for general partnership purposes. Partnership Agreement - Available cash, as defined in our Partnership Agreement generally will be distributed to our general partner and limited partners according to their partnership percentages of 2 percent and 98 percent, respectively. Our general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in our Partnership Agreement, our general partner receives: • 15 percent of amounts distributed in excess of $0.3025 per unit; • 25 percent of amounts distributed in excess of $0.3575 per unit; and • 50 percent of amounts distributed in excess of $0.4675 per unit. Cash Distributions - The following table sets forth the quarterly cash distribution declared and paid on each of our common and Class B units during the periods indicated: Declared for Quarter Ending Distribution Per Unit Date Declared Date Paid December 31, 2016 $ 0.790 January 18, 2017 February 14, 2017 September 30, 2016 $ 0.790 October 19, 2016 November 14, 2016 June 30, 2016 $ 0.790 July 28, 2016 August 14, 2016 March 31, 2016 $ 0.790 April 21, 2016 May 13, 2016 December 31, 2015 $ 0.790 January 21, 2016 February 12, 2016 September 30, 2015 $ 0.790 October 21, 2015 November 13, 2015 June 30, 2015 $ 0.790 July 23, 2015 August 14, 2015 March 31, 2015 $ 0.790 April 16, 2015 May 15, 2015 December 31, 2014 $ 0.790 January 15, 2015 February 13, 2015 September 30, 2014 $ 0.775 October 23, 2014 November 14, 2014 June 30, 2014 $ 0.760 July 25, 2014 August 14, 2014 March 31, 2014 $ 0.745 April 18, 2014 May 15, 2014 December 31, 2013 $ 0.730 January 16, 2014 February 14, 2014 The following table shows our distributions paid during the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands, except per unit amounts ) Distribution per unit $ 3.16 $ 3.16 $ 3.01 General partner distributions $ 26,640 $ 24,610 $ 21,044 Incentive distributions 402,152 371,500 304,999 Distributions to general partner 428,792 396,110 326,043 Limited partner distributions to ONEOK 361,292 310,230 279,292 Limited partner distributions to other unitholders 541,919 524,135 446,910 Total distributions paid $ 1,332,003 $ 1,230,475 $ 1,052,245 Distributions are declared and paid within 45 days of the completion of each quarter. The following table shows our distributions declared for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands, except per unit amounts ) Distribution per unit $ 3.16 $ 3.16 $ 3.07 General partner distributions $ 26,640 $ 25,356 $ 22,109 Incentive distributions 402,152 382,759 326,022 Distributions to general partner 428,792 408,115 348,131 Limited partner distributions to ONEOK 361,292 327,250 284,860 Limited partner distributions to other unitholders 541,919 532,405 472,466 Total distributions declared $ 1,332,003 $ 1,267,770 $ 1,105,457 Our Class B limited partner units are entitled to receive increased quarterly distributions equal to 110 percent of the distributions paid with respect to our common units. ONEOK, as the sole holder of our Class B limited partner units, has waived its right to receive the increased quarterly distributions on the Class B units. ONEOK retains the option to withdraw its waiver of increased distributions on Class B units at any time by giving us no less than 90 days advance notice. Any such withdrawal of the waiver will be effective with respect to any distribution on the Class B units declared or paid on or after the 90 days following delivery of the notice. The Class B units are eligible to convert into common units on a one-for-one basis at ONEOK’s option. If our common unitholders vote at any time to remove ONEOK or its affiliates as our general partner, quarterly distributions payable on the Class B limited partner units would increase to 123.5 percent of the distributions payable with respect to the common units, and distributions payable upon liquidation of the Class B limited partner units would increase to 123.5 percent of the distributions payable with respect to the common units. Our income is allocated to the general partner and the limited partners in accordance with their respective partnership percentages, after giving effect to any priority income allocations for incentive distributions that are allocated to the general partner. Noncontrolling Interest - In November 2014, we completed the acquisition of an 80 percent interest in the WTLPG. We consolidate WTLPG and record noncontrolling interests in consolidated subsidiaries in our consolidated financial statements to recognize the portion of WTLPG that we do not own.

RELATED-PARTY TRANSACTIONS (Not

RELATED-PARTY TRANSACTIONS (Notes)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
RELATED-PARTY TRANSACTIONS	RELATED-PARTY TRANSACTIONS On January 31, 2017, we and ONEOK entered into the Merger Agreement in which ONEOK will acquire all of our outstanding common units representing limited partner interests in us not already directly or indirectly owned by ONEOK. For additional information on this transaction, see Note B . Under the Services Agreement with ONEOK and ONEOK Partners GP (the Services Agreement), our operations and the operations of ONEOK and its affiliates can combine or share certain common services in order to operate more efficiently and cost effectively. Under the Services Agreement, ONEOK provides to us similar services that it provides to its affiliates, including those services required to be provided pursuant to our Partnership Agreement. ONEOK Partners GP may purchase services from ONEOK and its affiliates pursuant to the terms of the Services Agreement. ONEOK Partners GP has no employees and utilizes the services of ONEOK to fulfill its operating obligations. ONEOK and its affiliates provide a variety of services to us under the Services Agreement, including cash management and financial services, employee benefits provided through ONEOK’s benefit plans, legal and administrative services, insurance and office space leased in ONEOK’s headquarters building and other field locations. Where costs are incurred specifically on behalf of one of our affiliates, the costs are billed directly to us by ONEOK. In other situations, the costs may be allocated to us through a variety of methods, depending upon the nature of the expense and activities. Beginning in the second quarter 2014, ONEOK allocates substantially all of its general overhead costs to us as a result of ONEOK’s separation of its natural gas distribution business and the wind down of its energy services business in the first quarter 2014. For the first quarter 2014, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis. All costs directly charged or allocated to us are included in our Consolidated Statements of Income. Commodity sales and services revenues for transactions with ONE Gas prior to its separation from ONEOK on January 31, 2014, are reflected as affiliate transactions. Transactions with ONE Gas that occurred after the separation are reflected as unaffiliated, third-party transactions. On March 31, 2014, ONEOK completed the wind down of ONEOK Energy Services Company, a subsidiary of ONEOK. For the first quarter 2014, we had transactions with ONEOK Energy Services Company, which are reflected as affiliate transactions. The following table sets forth the transactions with related parties for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Revenues $ — $ — $ 53,526 Expenses Cost of sales and fuel $ — $ — $ 10,835 Operating expenses 388,142 368,346 330,541 Total expenses $ 388,142 $ 368,346 $ 341,376 ONEOK Partners GP made additional general partner contributions to us of approximately $21.0 million and $23.2 million in 2015 and 2014, respectively, to maintain its 2 percent general partner interest in connection with the issuances of common units. See Note H for additional information about cash distributions paid to ONEOK for its general partner and limited partner interests. We have an operating agreement with Roadrunner that provides for reimbursement or payment to us for management services and certain operating costs. Charges to Roadrunner included in operating income in our Consolidated Statements of Income for 2016 and 2015 were $7.7 million and $5.4 million , respectively.

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Notes)	12 Months Ended
	Dec. 31, 2016
ACCUMULATED OTHER COMPREHENSIVE LOSS	ACCUMULATED OTHER COMPREHENSIVE LOSS The following table sets forth the balance in accumulated other comprehensive loss for the periods indicated: Unrealized Gains Unrealized Gains Accumulated ( Thousands of dollars ) January 1, 2015 $ (91,823 ) $ — $ (91,823 ) Other comprehensive income (loss) before reclassifications 47,500 (1,925 ) 45,575 Amounts reclassified from accumulated other comprehensive loss (67,034 ) — (67,034 ) Other comprehensive income (loss) attributable to ONEOK Partners (19,534 ) (1,925 ) (21,459 ) December 31, 2015 (111,357 ) (1,925 ) (113,282 ) Other comprehensive income (loss) before reclassifications (35,752 ) (1,838 ) (37,590 ) Amounts reclassified from accumulated other comprehensive loss (10,717 ) 63 (10,654 ) Other comprehensive income (loss) attributable to ONEOK Partners (46,469 ) (1,775 ) (48,244 ) December 31, 2016 $ (157,826 ) $ (3,700 ) $ (161,526 ) The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our Consolidated Statements of Income for the periods indicated: Details about Accumulated Other Comprehensive Loss Components Years Ended December 31, Affected Line Item in the Consolidated Statements of Income 2016 2015 2014 ( Thousands of dollars ) Unrealized gains (losses) on risk-management assets/liabilities Commodity contracts $ 26,422 $ 81,089 $ (21,052 ) Commodity sales revenues Interest-rate contracts (15,705 ) (14,055 ) (10,601 ) Interest expense $ 10,717 $ 67,034 $ (31,653 ) Net income attributable to ONEOK Partners Unrealized Gains (Losses) on Risk-Management Assets/Liabilities of Unconsolidated Affiliates Interest-rate contracts $ (63 ) $ — $ — Equity in net earnings from investments Total reclassifications for the period attributable to ONEOK Partners $ 10,654 $ 67,034 $ (31,653 ) Net income attributable to ONEOK Partners

LIMITED PARTNERS' NET INCOME PE

LIMITED PARTNERS' NET INCOME PER UNIT LIMITED PARTNERS' NET INCOME PER UNIT (Notes)	12 Months Ended
	Dec. 31, 2016
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
LIMITED PARTNERS' NET INCOME PER UNIT	LIMITED PARTNERS’ NET INCOME PER UNIT Limited partners’ net income per unit is computed by dividing net income attributable to ONEOK Partners, L.P., after deducting the general partner’s allocation as discussed below, by the weighted-average number of outstanding limited partner units, which includes our common and Class B limited partner units. Because ONEOK has conditionally waived its right to increased quarterly distributions, until it gives 90 days notice of the withdrawal of the waiver, currently each Class B and common unit share equally in the earnings of the Partnership, and neither has any liquidation or other preferences. ONEOK Partners GP owns the entire 2 percent general partnership interest in us, which entitles it to incentive distribution rights that provide for an increasing proportion of cash distributions from the Partnership as the distributions made to limited partners increase above specified levels. For purposes of our calculation of limited partners’ net income per unit, net income attributable to ONEOK Partners, L.P. is allocated to the general partner as follows: (i) an amount based upon the 2 percent general partner interest in net income attributable to ONEOK Partners, L.P.; and (ii) the amount of the general partner’s incentive distribution rights based on the total cash distributions declared for the period. The amount of incentive distributions allocated to our general partner totaled $402.2 million , $382.8 million and $326.0 million for 2016, 2015 and 2014 , respectively. The terms of our Partnership Agreement limit the general partner’s incentive distribution to the amount of available cash calculated for the period. As such, incentive distribution rights are not allocated on undistributed earnings. For additional information regarding our general partner’s incentive distribution rights, see “Partnership Agreement” in Note H .

INCOME TAXES (Notes)

INCOME TAXES (Notes)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The following table sets forth our provision for income taxes for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Current income tax provision Federal $ — $ — $ 59 State 1,830 (621 ) 1,777 Total current income tax provision 1,830 (621 ) 1,836 Deferred income tax provision Federal 8,705 5,413 5,033 State 3,365 (648 ) 5,799 Total deferred income tax provision 12,070 4,765 10,832 Total provision for income taxes $ 13,900 $ 4,144 $ 12,668 The following table is a reconciliation of our income tax provision for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Income before income taxes $ 1,086,164 $ 602,016 $ 924,003 Less: Net income attributable to noncontrolling interests 5,497 8,330 1,037 Income attributable to ONEOK Partners, L.P. before income taxes 1,080,667 593,686 922,966 Federal statutory income tax rate 35.0 % 35.0 % 35.0 % Provision for federal income taxes 378,233 207,790 323,038 Partnership earnings not subject to tax (370,059 ) (202,143 ) (318,021 ) State income taxes, net of federal benefit 5,067 (2,078 ) 7,576 State deferred tax rate change, net of valuation allowance 128 810 — Other, net 531 (235 ) 75 Income tax provision $ 13,900 $ 4,144 $ 12,668 The following table sets forth the tax effects of temporary differences that gave rise to significant portions of the deferred tax assets and liabilities for the periods indicated: Years Ended December 31, 2016 2015 ( Thousands of dollars ) Deferred tax assets Federal and state net operating loss $ 8,293 $ 4,224 Other 4 7 Total deferred tax assets 8,297 4,231 Deferred tax liabilities Excess of tax over book depreciation 83,731 67,265 Regulatory assets 33 49 Total deferred tax liabilities 83,764 67,314 Net deferred tax liabilities $ 75,467 $ 63,083

UNCONSOLIDATED AFFILIATES (Note

UNCONSOLIDATED AFFILIATES (Notes)	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
UNCONSOLIDATED AFFILIATES	UNCONSOLIDATED AFFILIATES Investments in Unconsolidated Affiliates - The following table sets forth our investments in unconsolidated affiliates for the periods indicated: Net Ownership Interest December 31, December 31, ( Thousands of dollars ) Northern Border Pipeline 50% $ 328,456 $ 363,231 Overland Pass Pipeline Company 50% 444,138 459,354 Other Various 186,213 125,636 Investments in unconsolidated affiliates (a) $ 958,807 $ 948,221 (a) - Equity-method goodwill (Note A ) was $40.1 million at December 31, 2016 and 2015 , respectively. Equity in Net Earnings from Investments and Impairments - The following table sets forth our equity in net earnings from investments for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Northern Border Pipeline $ 69,990 $ 66,941 $ 69,819 Overland Pass Pipeline Company 53,984 37,783 25,906 Other 15,716 20,576 21,690 Equity in net earnings from investments $ 139,690 $ 125,300 $ 117,415 Impairment of equity investments $ — $ (180,583 ) $ (76,412 ) Unconsolidated Affiliates Financial Information - The following tables set forth summarized combined financial information of our unconsolidated affiliates for the periods indicated: December 31, December 31, ( Thousands of dollars ) Balance Sheet Current assets $ 143,317 $ 149,439 Property, plant and equipment, net $ 2,579,607 $ 2,556,559 Other noncurrent assets $ 20,784 $ 23,722 Current liabilities $ 77,388 $ 211,037 Long-term debt $ 649,539 $ 425,521 Other noncurrent liabilities $ 69,265 $ 69,356 Accumulated other comprehensive loss $ (7,450 ) $ (5,669 ) Owners’ equity $ 1,954,966 $ 2,029,475 Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Income Statement Operating revenues $ 578,542 $ 524,496 $ 548,491 Operating expenses (a) $ 260,753 $ 304,930 $ 309,990 Net income (a) $ 293,921 $ 200,064 $ 214,410 Distributions paid to us $ 196,717 $ 155,918 $ 139,019 (a) Includes long-lived asset impairment charges in 2015 and 2014. We incurred expenses in transactions with unconsolidated affiliates of $140.3 million , $104.7 million and $62.0 million for 2016, 2015 and 2014 , respectively, primarily related to Overland Pass Pipeline Company and Northern Border Pipeline. Accounts payable to our equity-method investees at December 31, 2016 and 2015, was $11.1 million and $8.0 million , respectively. Northern Border Pipeline - The Northern Border Pipeline partnership agreement provides that distributions to Northern Border Pipeline’s partners are to be made on a pro rata basis according to each partner’s percentage interest. The Northern Border Pipeline Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distribution policy of Northern Border Pipeline requires the unanimous approval of the Northern Border Pipeline Management Committee. Cash distributions are equal to 100 percent of distributable cash flow as determined from Northern Border Pipeline’s financial statements based upon EBITDA less interest expense and maintenance capital expenditures. Loans or other advances from Northern Border Pipeline to its partners or affiliates are prohibited under its credit agreement. Overland Pass Pipeline Company - The Overland Pass Pipeline Company limited liability company agreement provides that distributions to Overland Pass Pipeline Company’s members are to be made on a pro rata basis according to each member’s percentage interest. The Overland Pass Pipeline Company Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distributions from Overland Pass Pipeline Company requires the unanimous approval of the Overland Pass Pipeline Management Committee. Cash distributions are equal to 100 percent of available cash as defined in the limited liability company agreement. Roadrunner Gas Transmission - In March 2015, we entered into a 50-50 joint venture with a subsidiary of Fermaca, a Mexico City-based natural gas infrastructure company, to construct the Roadrunner pipeline to transport natural gas from the Permian Basin in West Texas to the Mexican border near El Paso, Texas. We contributed approximately $65 million and $30 million to Roadrunner in 2016 and 2015, respectively. The Roadrunner limited liability agreement provides that distributions to members are made on a pro rata basis according to each member’s ownership interest. The Roadrunner Management Committee determines the amount and timing of such distributions. Cash distributions are equal to 100 percent of available cash, as defined in the limited liability company agreement. Impairment Charges - Due to the continued and greater than expected decline in volumes gathered in the dry natural gas area of the Powder River Basin, we evaluated our long-lived assets and equity investments in this area in 2015 and made the decision to cease operations of our wholly owned coal-bed methane natural gas gathering system in 2016. Bighorn Gas Gathering, in which we own a 49 percent equity interest, and Fort Union Gas Gathering, in which we own a 37 percent equity interest, are both partially supplied with volumes from our wholly owned coal-bed methane natural gas gathering system. We own a 35 percent equity interest in Lost Creek Gathering Company, which also is located in a dry natural gas area. We reviewed our Bighorn Gas Gathering, Fort Union Gas Gathering and Lost Creek Gathering Company equity investments and recorded noncash impairment charges of $180.6 million in 2015. The remaining net book value of our equity investments in this dry natural gas area is $31.1 million as of December 31, 2016. In 2014, Bighorn Gas Gathering recorded an impairment of its underlying assets when the operator determined that the volume decline would be sustained for the foreseeable future. As a result, we reviewed our equity investment in Bighorn Gas Gathering for impairment and recorded noncash impairment charges of $76.4 million in 2014.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Notes)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Commitments - Operating leases represent future minimum lease payments under noncancelable leases covering office space and pipeline equipment. Rental expense in 2016, 2015 and 2014 was not material. We have no material operating leases. Firm transportation and storage contracts are fixed-price contracts that provide us with firm transportation and storage capacity. The following table sets forth our firm transportation and storage contract payments for our continuing operations for the periods indicated: Firm Transportation and Storage Contracts ( Millions of dollars ) 2017 $ 51.5 2018 43.0 2019 37.5 2020 37.1 2021 23.0 Thereafter 35.0 Total $ 227.1 Environmental Matters and Pipeline Safety - The operation of pipelines, plants and other facilities for the gathering, processing, transportation and storage of natural gas, NGLs, condensate, and other products is subject to numerous and complex laws and regulations pertaining to health, safety and the environment. As an owner and/or operator of these facilities we must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our results of operations, financial condition or cash flows. 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.

ACQUISITIONS ACQUISITIONS (Note

ACQUISITIONS ACQUISITIONS (Notes)	12 Months Ended
	Dec. 31, 2016
Acquisition [Abstract]
ACQUISITIONS	ACQUISITIONS In November 2014 , we completed the acquisition of an 80 percent interest in WTLPG and a 100 percent interest in the Mesquite Pipeline for approximately $800 million from affiliates of Chevron Corporation, and we became the operator of both pipelines. Financing to close this transaction came from available cash on hand and borrowings under our existing commercial paper program. We accounted for the West Texas LPG acquisition as a business combination which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values. The final purchase price allocation and assessment of the fair value of the assets acquired as of the acquisition date were as follows: ( Thousands of dollars ) Cash $ 13,839 Accounts receivable 9,132 Other current assets 3,369 Property, plant and equipment Regulated 812,716 Nonregulated 157,643 Total property, plant and equipment 970,359 Total fair value of assets acquired 996,699 Accounts payable (8,621 ) Other liabilities (10,867 ) Total fair value of liabilities acquired (19,488 ) Less: Fair value of noncontrolling interest (162,438 ) Net assets acquired 814,773 Less: Cash received (13,839 ) Net cash paid for acquisition $ 800,934 Beginning November 29, 2014, the results of operations for West Texas LPG are included in our Natural Gas Liquids segment. We consolidate WTLPG and have recorded noncontrolling interests in consolidated subsidiaries on our Consolidated Statements of Income and Consolidated Balance Sheets to recognize the portion of WTLPG that we do not own. The portion of the assets and liabilities of WTLPG acquired attributable to noncontrolling interests was accounted for as noncash activity. The fair value of the noncontrolling interest of WTLPG was estimated by applying a market approach. Revenues and earnings related to West Texas LPG have been included within the Consolidated Statements of Income since the acquisition date. Supplemental pro forma revenue and earnings reflecting this acquisition as if it had occurred as of January 1, 2014, are not materially different from the information presented in the accompanying Consolidated Statements of Income and are, therefore, not presented. The limited partnership agreement of WTLPG provides that cash distributions to the partners are to be made on a pro rata basis according to each partner’s ownership interest. Cash distributions are equal to 100 percent of distributable cash as defined in the limited partnership agreement of WTLPG. Any changes to, or suspension of, the cash distributions from WTLPG requires the approval of a minimum of 90 percent of the ownership interest and a minimum of two general partners of WTLPG.

SEGMENTS (Notes)

SEGMENTS (Notes)	12 Months Ended
	Dec. 31, 2016
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. Accounting Policies - The accounting policies of the segments are described in Note A . Our chief operating decision-maker reviews the financial performance of each of our three segments, as well as the financial performance of the Partnership as a whole, on a regular basis. Beginning in 2016, adjusted EBITDA by segment is utilized in this evaluation. We believe this 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 are commonly employed by financial analysts and others to evaluate our financial performance and to compare financial performance among companies in our industry. Adjusted EBITDA for each segment is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes, allowance for equity funds used during construction and other noncash items. This calculation may not be comparable with similarly titled measures of other companies. Prior period segment disclosures have been recast to reflect this change. As a result of ONEOK’s separation of its natural gas distribution business into a stand-alone publicly traded company called ONE Gas on January 31, 2014, transactions with ONE Gas subsequent to the separation are reflected as sales to unaffiliated customers. Customers - The primary customers of our Natural Gas Gathering and Processing segment are crude oil and natural gas producers, which include both large integrated and independent exploration and production companies. Our Natural Gas Liquids segment’s customers are primarily NGL and natural gas gathering and processing companies; large integrated and independent crude oil and natural gas production companies; propane distributors; ethanol producers; and petrochemical, refining and NGL marketing companies. Our Natural Gas Pipelines segment’s customers are primarily local natural gas distribution companies, electric-generation companies, large industrial companies, municipalities, irrigation customers and marketing companies. For each of the years ended December 31, 2016, 2015 and 2014 , we had no single customer from which we received 10 percent or more of our consolidated revenues. See Note M for additional information about our sales to affiliated customers. Operating Segment Information - The following tables set forth certain selected financial information for our operating segments for the periods indicated: Year Ended December 31, 2016 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,375,738 $ 7,168,983 $ 373,738 $ 8,918,459 Intersegment revenues 675,839 506,671 5,623 1,188,133 Total revenues 2,051,577 7,675,654 379,361 10,106,592 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (1,331,542 ) (6,321,377 ) (30,561 ) (7,683,480 ) Operating costs (285,599 ) (327,597 ) (115,628 ) (728,824 ) Equity in net earnings from investments 10,742 54,513 74,435 139,690 Other 1,600 (1,574 ) 5,530 5,556 Segment adjusted EBITDA $ 446,778 $ 1,079,619 $ 313,137 $ 1,839,534 Depreciation and amortization $ (178,548 ) $ (163,303 ) $ (46,718 ) $ (388,569 ) Total assets $ 5,320,666 $ 8,347,961 $ 1,946,318 $ 15,614,945 Capital expenditures $ 410,485 $ 105,861 $ 96,274 $ 612,620 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1.2 billion , of which $992.8 million related to sales within the segment, cost of sales and fuel of $458.7 million and operating income of $467.9 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $238.7 million , cost of sales and fuel of $30.0 million and operating income of $100.8 million . Year Ended December 31, 2016 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 8,918,459 $ — $ 8,918,459 Intersegment revenues 1,188,133 (1,188,133 ) — Total revenues $ 10,106,592 $ (1,188,133 ) $ 8,918,459 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (7,683,480 ) $ 1,187,356 $ (6,496,124 ) Operating costs $ (728,824 ) $ 1,266 $ (727,558 ) Depreciation and amortization $ (388,569 ) $ — $ (388,569 ) Equity in net earnings from investments $ 139,690 $ — $ 139,690 Total assets $ 15,614,945 $ (145,598 ) $ 15,469,347 Capital expenditures $ 612,620 $ 9,102 $ 621,722 Year Ended December 31, 2015 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,187,390 $ 6,248,002 $ 325,676 $ 7,761,068 Intersegment revenues 649,726 331,697 6,771 988,194 Total revenues 1,837,116 6,579,699 332,447 8,749,262 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (1,265,617 ) (5,328,256 ) (34,481 ) (6,628,354 ) Operating costs (272,418 ) (314,505 ) (105,720 ) (692,643 ) Equity in net earnings from investments 17,863 38,696 68,741 125,300 Other 1,610 (3,342 ) 13,993 12,261 Segment adjusted EBITDA $ 318,554 $ 972,292 $ 274,980 $ 1,565,826 Depreciation and amortization $ (150,008 ) $ (158,709 ) $ (43,479 ) $ (352,196 ) Impairment of long-lived assets $ (73,681 ) $ (9,992 ) $ — $ (83,673 ) Impairment of equity investments $ (180,583 ) $ — $ — $ (180,583 ) Total assets $ 5,123,450 $ 8,017,799 $ 1,851,857 $ 14,993,106 Capital expenditures $ 887,938 $ 226,135 $ 58,215 $ 1,172,288 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $954.8 million , of which $770.1 million related to sales within the segment, cost of sales and fuel of $412.6 million and operating income of $306.9 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $266.9 million , cost of sales and fuel of $31.1 million and operating income of $103.7 million . Year Ended December 31, 2015 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 7,761,068 $ — $ 7,761,068 Intersegment revenues 988,194 (988,194 ) — Total revenues $ 8,749,262 $ (988,194 ) $ 7,761,068 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (6,628,354 ) $ 987,302 $ (5,641,052 ) Operating costs $ (692,643 ) $ 467 $ (692,176 ) Depreciation and amortization $ (352,196 ) $ — $ (352,196 ) Impairment of long-lived assets $ (83,673 ) $ — $ (83,673 ) Impairment of equity investments $ (180,583 ) $ — $ (180,583 ) Equity in net earnings from investments $ 125,300 $ — $ 125,300 Total assets $ 14,993,106 $ (65,520 ) $ 14,927,586 Capital expenditures $ 1,172,288 $ 13,835 $ 1,186,123 Year Ended December 31, 2014 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,478,729 $ 10,329,609 $ 329,801 $ 12,138,139 Sales to affiliated customers 41,214 — 12,312 53,526 Intersegment revenues 1,447,665 215,772 8,343 1,671,780 Total revenues 2,967,608 10,545,381 350,456 13,863,445 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (2,305,723 ) (9,435,296 ) (21,935 ) (11,762,954 ) Operating costs (257,658 ) (296,402 ) (111,037 ) (665,097 ) Equity in net earnings from investments 20,271 27,326 69,818 117,415 Other 672 (87 ) 6,900 7,485 Segment adjusted EBITDA $ 425,170 $ 840,922 $ 294,202 $ 1,560,294 Depreciation and amortization $ (123,847 ) $ (124,071 ) $ (43,318 ) $ (291,236 ) Impairment of equity investments $ (76,412 ) $ — $ — $ (76,412 ) Total assets $ 4,911,283 $ 8,143,575 $ 1,835,884 $ 14,890,742 Capital expenditures $ 898,896 $ 798,048 $ 42,991 $ 1,739,935 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $695.9 million , of which $598.1 million related to sales within the segment, cost of sales and fuel of $309.4 million and operating income of $196.1 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $290.0 million , cost of sales and fuel of $47.7 million and operating income of $106.5 million . Year Ended December 31, 2014 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 12,138,139 $ — $ 12,138,139 Sales to affiliated customers 53,526 — 53,526 Intersegment revenues 1,671,780 (1,671,780 ) — Total revenues $ 13,863,445 $ (1,671,780 ) $ 12,191,665 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (11,762,954 ) $ 1,674,406 $ (10,088,548 ) Operating costs $ (665,097 ) $ (4,560 ) $ (669,657 ) Depreciation and amortization $ (291,236 ) $ — $ (291,236 ) Impairment of equity investments $ (76,412 ) $ — $ (76,412 ) Equity in net earnings from investments $ 117,415 $ — $ 117,415 Total assets $ 14,890,742 $ (290,342 ) $ 14,600,400 Capital expenditures $ 1,739,935 $ 6,055 $ 1,745,990 Years Ended December 31, ( Unaudited ) 2016 2015 2014 Reconciliation of net income to total segment adjusted EBITDA ( Thousands of dollars ) Net income $ 1,072,264 $ 597,872 $ 911,335 Add: Interest expense, net of capitalized interest 366,789 338,911 281,908 Depreciation and amortization 388,569 352,196 291,236 Income taxes 13,900 4,144 12,668 Impairment charges — 264,256 76,412 Allowance for equity funds used during construction and other (1,988 ) 8,447 (13,265 ) Total segment adjusted EBITDA $ 1,839,534 $ 1,565,826 $ 1,560,294

QUARTERLY FINANCIAL DATA (UNAUD

QUARTERLY FINANCIAL DATA (UNAUDITED) (Notes)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Data [Abstract]
QUARTERLY FINANCIAL DATA (UNAUDITED)	QUARTERLY FINANCIAL DATA (UNAUDITED) Year Ended December 31, 2016 First Quarter Second Quarter Third Quarter Fourth Quarter ( Thousands of dollars, except per unit amounts ) Revenues $ 1,773,945 $ 2,133,594 $ 2,357,391 $ 2,653,529 Net income $ 256,286 $ 261,964 $ 275,411 $ 278,603 Net income attributable to ONEOK Partners, L.P. $ 253,517 $ 261,468 $ 274,308 $ 277,474 Limited partners’ per unit net income $ 0.52 $ 0.54 $ 0.59 $ 0.60 Year Ended December 31, 2015 First Quarter Second Quarter Third Quarter Fourth Quarter ( Thousands of dollars, except per unit amounts ) Revenues $ 1,804,759 $ 2,127,507 $ 1,898,418 $ 1,930,384 Net income $ 147,032 $ 211,610 $ 229,665 $ 9,565 Net income attributable to ONEOK Partners, L.P. $ 145,594 $ 209,770 $ 226,961 $ 7,217 Limited partners’ per unit net income (loss) $ 0.21 $ 0.44 $ 0.45 $ (0.33 ) The fourth quarter 2015 includes noncash impairment charges of $264.3 million related to long-lived assets and equity investments.

SUPPLEMENTAL CONDENSED CONSOLID

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Notes)	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Supplemental Condensed Consolidating Financial Information	SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION We have no significant assets or operations other than our investment in our wholly owned subsidiary, the Intermediate Partnership. The Intermediate Partnership holds all our partnership interests and equity in our subsidiaries, as well as a 50 percent interest in Northern Border Pipeline. Our Intermediate Partnership guarantees our senior notes and borrowings, if any, under the Partnership Credit Agreement. The Intermediate Partnership’s guarantee of our senior notes and of any borrowings under the Partnership Credit Agreement are full and unconditional, subject to certain customary automatic release provisions. For purposes of the following footnote: • we are referred to as “Parent”; • the Intermediate Partnership is referred to as “Guarantor Subsidiary”; and • the “Non-Guarantor Subsidiaries” are all subsidiaries other than the Guarantor Subsidiary. The following supplemental condensed consolidating financial information is presented on an equity-method basis reflecting the Parent’s separate accounts, the Guarantor Subsidiary’s separate accounts, the combined accounts of the Non-Guarantor Subsidiaries, the combined consolidating adjustments and eliminations and the Parent’s consolidated amounts for the periods indicated. Condensed Consolidating Statements of Income Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 6,858.5 $ — $ 6,858.5 Services — — 2,060.0 — 2,060.0 Total revenues — — 8,918.5 — 8,918.5 Cost of sales and fuel (exclusive of items shown separately below) — — 6,496.1 — 6,496.1 Operating expenses — — 1,116.2 — 1,116.2 (Gain) loss on sale of assets — — (9.9 ) — (9.9 ) Operating income — — 1,316.1 — 1,316.1 Equity in net earnings from investments 1,066.8 1,066.8 69.7 (2,063.6 ) 139.7 Other income (expense), net 373.5 373.5 (2.8 ) (747.0 ) (2.8 ) Interest expense (373.5 ) (373.5 ) (366.8 ) 747.0 (366.8 ) Income before income taxes 1,066.8 1,066.8 1,016.2 (2,063.6 ) 1,086.2 Income taxes — — (13.9 ) — (13.9 ) Net income 1,066.8 1,066.8 1,002.3 (2,063.6 ) 1,072.3 Less: Net income attributable to noncontrolling interests — — 5.5 — 5.5 Net income attributable to ONEOK Partners, L.P. $ 1,066.8 $ 1,066.8 $ 996.8 $ (2,063.6 ) $ 1,066.8 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 6,098.3 $ — $ 6,098.3 Services — — 1,662.8 — 1,662.8 Total revenues — — 7,761.1 — 7,761.1 Cost of sales and fuel (exclusive of items shown separately below) — — 5,641.1 — 5,641.1 Impairment of long-lived assets — — 83.7 — 83.7 Operating expenses — — 1,044.3 — 1,044.3 (Gain) loss on sale of assets — — (6.1 ) — (6.1 ) Operating income — — 998.1 — 998.1 Equity in net earnings from investments 589.5 589.5 58.4 (1,112.1 ) 125.3 Impairment of equity investments — — (180.6 ) — (180.6 ) Other income (expense), net 371.0 371.0 (1.9 ) (742.0 ) (1.9 ) Interest expense (371.0 ) (371.0 ) (338.9 ) 742.0 (338.9 ) Income before income taxes 589.5 589.5 535.1 (1,112.1 ) 602.0 Income taxes — — (4.1 ) — (4.1 ) Net income 589.5 589.5 531.0 (1,112.1 ) 597.9 Less: Net income attributable to noncontrolling interests — — 8.4 — 8.4 Net income attributable to ONEOK Partners, L.P. $ 589.5 $ 589.5 $ 522.6 $ (1,112.1 ) $ 589.5 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 10,725.0 $ — $ 10,725.0 Services — — 1,466.7 — 1,466.7 Total revenues — — 12,191.7 — 12,191.7 Cost of sales and fuel (exclusive of items shown separately below) — — 10,088.6 — 10,088.6 Operating expenses — — 960.9 — 960.9 (Gain) loss on sale of assets — — (6.6 ) — (6.6 ) Operating income — — 1,148.8 — 1,148.8 Equity in net earnings from investments 910.3 910.3 47.6 (1,750.8 ) 117.4 Impairment of equity investments — — (76.4 ) — (76.4 ) Other income (expense), net 331.7 331.7 16.1 (663.4 ) 16.1 Interest expense,net (331.7 ) (331.7 ) (281.9 ) 663.4 (281.9 ) Income before income taxes 910.3 910.3 854.2 (1,750.8 ) 924.0 Income taxes — — (12.7 ) — (12.7 ) Net income 910.3 910.3 841.5 (1,750.8 ) 911.3 Less: Net income attributable to noncontrolling interests — — 1.0 — 1.0 Net income attributable to ONEOK Partners, L.P. $ 910.3 $ 910.3 $ 840.5 $ (1,750.8 ) $ 910.3 Condensed Consolidating Statements of Comprehensive Income Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 1,066.8 $ 1,066.8 $ 1,002.3 $ (2,063.6 ) $ 1,072.3 Other comprehensive income (loss) Unrealized gains (losses) on derivatives (35.8 ) (78.5 ) (78.5 ) 157.0 (35.8 ) Realized (gains) losses on derivatives recognized in net income (10.7 ) (26.4 ) (26.4 ) 52.8 (10.7 ) Other comprehensive income (loss) on investments in unconsolidated affiliates (1.8 ) (1.8 ) (1.8 ) 3.6 (1.8 ) Total other comprehensive income (loss) (48.3 ) (106.7 ) (106.7 ) 213.4 (48.3 ) Comprehensive income 1,018.5 960.1 895.6 (1,850.2 ) 1,024.0 Less: Comprehensive income attributable to noncontrolling interests — — 5.5 — 5.5 Comprehensive income attributable to ONEOK Partners, L.P. $ 1,018.5 $ 960.1 $ 890.1 $ (1,850.2 ) $ 1,018.5 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 589.5 $ 589.5 $ 531.0 $ (1,112.1 ) $ 597.9 Other comprehensive income (loss) Unrealized gains (losses) on derivatives 47.5 70.1 70.1 (140.2 ) 47.5 Realized (gains) losses on derivatives recognized in net income (67.0 ) (81.1 ) (81.1 ) 162.2 (67.0 ) Other comprehensive income (loss) on investments in unconsolidated affiliates (1.9 ) (1.9 ) (1.9 ) 3.8 (1.9 ) Total other comprehensive income (loss) (21.4 ) (12.9 ) (12.9 ) 25.8 (21.4 ) Comprehensive income 568.1 576.6 518.1 (1,086.3 ) 576.5 Less: Comprehensive income attributable to noncontrolling interests — — 8.4 — 8.4 Comprehensive income attributable to ONEOK Partners, L.P. $ 568.1 $ 576.6 $ 509.7 $ (1,086.3 ) $ 568.1 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 910.3 $ 910.3 $ 841.5 $ (1,750.8 ) $ 911.3 Other comprehensive income (loss) Unrealized gains (losses) on derivatives (64.6 ) 32.4 32.4 (64.8 ) (64.6 ) Realized (gains) losses on derivatives recognized in net income 31.6 21.1 21.1 (42.2 ) 31.6 Total other comprehensive income (loss) (33.0 ) 53.5 53.5 (107.0 ) (33.0 ) Comprehensive income 877.3 963.8 895.0 (1,857.8 ) 878.3 Less: Comprehensive income attributable to noncontrolling interests — — 1.0 — 1.0 Comprehensive income attributable to ONEOK Partners, L.P. $ 877.3 $ 963.8 $ 894.0 $ (1,857.8 ) $ 877.3 Condensed Consolidating Balance Sheets December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total Assets ( Millions of dollars ) Current assets Cash and cash equivalents $ — $ 0.4 $ — $ — $ 0.4 Accounts receivable, net — — 872.3 — 872.3 Affiliate receivables — — 1.0 — 1.0 Natural gas and natural gas liquids in storage — — 140.0 — 140.0 Materials and supplies — — 60.9 — 60.9 Other current assets — — 99.6 — 99.6 Total current assets — 0.4 1,173.8 — 1,174.2 Property, plant and equipment Property, plant and equipment — — 14,854.7 — 14,854.7 Accumulated depreciation and amortization — — 2,392.0 — 2,392.0 Net property, plant and equipment — — 12,462.7 — 12,462.7 Investments and other assets Intercompany notes receivable 10,615.0 7,031.3 — (17,646.3 ) — Other assets 3,269.6 6,805.4 1,457.2 (9,699.8 ) 1,832.4 Total investments and other assets 13,884.6 13,836.7 1,457.2 (27,346.1 ) 1,832.4 Total assets $ 13,884.6 $ 13,837.1 $ 15,093.7 $ (27,346.1 ) $ 15,469.3 Liabilities and equity Current liabilities Current maturities of long-term debt $ 400.0 $ — $ 7.7 $ — $ 407.7 Short-term borrowings 1,110.3 — — — 1,110.3 Accounts payable — — 862.4 — 862.4 Affiliate payables — — 68.2 — 68.2 Other current liabilities 99.9 — 275.9 — 375.8 Total current liabilities 1,610.2 — 1,214.2 — 2,824.4 Intercompany debt — 10,615.0 7,031.3 (17,646.3 ) — Long-term debt, excluding current maturities 6,254.7 — 36.6 — 6,291.3 Deferred credits and other liabilities — — 175.8 — 175.8 Commitments and contingencies Equity Equity excluding noncontrolling interests in consolidated subsidiaries 6,019.7 3,222.1 6,477.7 (9,699.8 ) 6,019.7 Noncontrolling interests in consolidated subsidiaries — — 158.1 — 158.1 Total equity 6,019.7 3,222.1 6,635.8 (9,699.8 ) 6,177.8 Total liabilities and equity $ 13,884.6 $ 13,837.1 $ 15,093.7 $ (27,346.1 ) $ 15,469.3 December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total Assets ( Millions of dollars ) Current assets Cash and cash equivalents $ — $ 5.1 $ — $ — $ 5.1 Accounts receivable, net — — 593.4 — 593.4 Affiliate receivables — — 8.0 — 8.0 Natural gas and natural gas liquids in storage — — 128.1 — 128.1 Materials and supplies — — 76.7 — 76.7 Other current assets 4.1 — 67.8 — 71.9 Total current assets 4.1 5.1 874.0 — 883.2 Property, plant and equipment Property, plant and equipment — — 14,307.5 — 14,307.5 Accumulated depreciation and amortization — — 2,050.7 — 2,050.7 Net property, plant and equipment — — 12,256.8 — 12,256.8 Investments and other assets Intercompany notes receivable 10,144.9 7,781.8 — (17,926.7 ) — Other assets 3,594.0 5,952.0 1,425.2 (9,183.6 ) 1,787.6 Total investments and other assets 13,738.9 13,733.8 1,425.2 (27,110.3 ) 1,787.6 Total assets $ 13,743.0 $ 13,738.9 $ 14,556.0 $ (27,110.3 ) $ 14,927.6 Liabilities and equity Current liabilities Current maturities of long-term debt $ 100.0 $ — $ 7.7 $ — $ 107.7 Short-term borrowings 546.3 — — — 546.3 Accounts payable — — 605.4 — 605.4 Affiliate payables — — 27.1 — 27.1 Other current liabilities 112.5 — 181.4 — 293.9 Total current liabilities 758.8 — 821.6 — 1,580.4 Intercompany debt — 10,144.9 7,781.8 (17,926.7 ) — Long-term debt, excluding current maturities 6,651.0 — 44.3 — 6,695.3 Deferred credits and other liabilities — — 154.6 — 154.6 Commitments and contingencies Equity Equity excluding noncontrolling interests in consolidated subsidiaries 6,333.2 3,594.0 5,589.6 (9,183.6 ) 6,333.2 Noncontrolling interests in consolidated subsidiaries — — 164.1 — 164.1 Total equity 6,333.2 3,594.0 5,753.7 (9,183.6 ) 6,497.3 Total liabilities and equity $ 13,743.0 $ 13,738.9 $ 14,556.0 $ (27,110.3 ) $ 14,927.6 Condensed Consolidating Statements of Cash Flows Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,334.5 $ 70.0 $ 1,414.3 $ (1,332.0 ) $ 1,486.8 Investing activities Capital expenditures — — (621.7 ) — (621.7 ) Other investing activities — 34.9 (25.8 ) — 9.1 Cash provided by (used in) investing activities — 34.9 (647.5 ) — (612.6 ) Financing activities Cash distributions: General and limited partners (1,332.0 ) (1,332.0 ) — 1,332.0 (1,332.0 ) Noncontrolling interests — — (7.5 ) — (7.5 ) Intercompany borrowings (advances), net (470.8 ) 1,222.4 (751.6 ) — — Borrowing (repayment) of short-term borrowings, net 563.9 — — — 563.9 Issuance of long-term debt, net of discounts 1,000.0 — — — 1,000.0 Debt financing costs (2.8 ) — — — (2.8 ) Repayment of long-term debt (1,100.0 ) — (7.7 ) — (1,107.7 ) Other 7.2 — — — 7.2 Cash provided by (used in) financing activities (1,334.5 ) (109.6 ) (766.8 ) 1,332.0 (878.9 ) Change in cash and cash equivalents — (4.7 ) — — (4.7 ) Cash and cash equivalents at beginning of period — 5.1 — — 5.1 Cash and cash equivalents at end of period $ — $ 0.4 $ — $ — $ 0.4 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,196.7 $ 66.9 $ 1,038.9 $ (1,230.5 ) $ 1,072.0 Investing activities Capital expenditures — — (1,186.1 ) — (1,186.1 ) Other investing activities — 24.1 (26.5 ) — (2.4 ) Cash provided by (used in) investing activities — 24.1 (1,212.6 ) — (1,188.5 ) Financing activities Cash distributions: General and limited partners (1,230.5 ) (1,230.5 ) — 1,230.5 (1,230.5 ) Noncontrolling interests — — (11.7 ) — (11.7 ) Intercompany borrowings (advances), net (1,295.1 ) 1,102.1 193.0 — — Borrowing (repayment) of short-term borrowings, net (509.0 ) — — — (509.0 ) Issuance of long-term debt, net of discounts 798.9 — — — 798.9 Debt financing costs (7.7 ) — — — (7.7 ) Repayment of long-term debt — — (7.6 ) — (7.6 ) Issuance of common units, net of issuance costs 1,025.7 — — — 1,025.7 Contribution from general partner 21.0 — — — 21.0 Cash provided by (used in) financing activities (1,196.7 ) (128.4 ) 173.7 1,230.5 79.1 Change in cash and cash equivalents — (37.4 ) — — (37.4 ) Cash and cash equivalents at beginning of period — 42.5 — — 42.5 Cash and cash equivalents at end of period $ — $ 5.1 $ — $ — $ 5.1 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,155.7 $ 69.8 $ 1,136.5 $ (1,052.2 ) $ 1,309.8 Investing activities Capital expenditures — — (1,746.0 ) — (1,746.0 ) Other investing activities — 17.7 (804.7 ) — (787.0 ) Cash provided by (used in) investing activities — 17.7 (2,550.7 ) — (2,533.0 ) Financing activities Cash distributions: General and limited partners (1,052.2 ) (1,052.2 ) — 1,052.2 (1,052.2 ) Noncontrolling interests — — (0.6 ) — (0.6 ) Intercompany borrowings (advances), net (2,295.2 ) 872.7 1,422.5 — — Borrowing (repayment) of short-term borrowings, net 1,055.3 — — — 1,055.3 Repayment of long-term debt — — (7.7 ) — (7.7 ) Issuance of common units, net of issuance costs 1,113.1 — — — 1,113.1 Contribution from general partner 23.3 — — — 23.3 Cash provided by (used in) financing activities (1,155.7 ) (179.5 ) 1,414.2 1,052.2 1,131.2 Change in cash and cash equivalents — (92.0 ) — — (92.0 ) Cash and cash equivalents at beginning of period — 134.5 — — 134.5 Cash and cash equivalents at end of period $ — $ 42.5 $ — $ — $ 42.5

SUMMARY OF SIGNIFICANT ACCOUN27

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncements	The following tables provide a brief description of recent accounting pronouncements and our analysis of the effects on our financial statements: Standard Description Date of Adoption Effect on the Financial Statements or Other Significant Matters Standards that were adopted ASU 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments” The standard requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. First quarter 2016 There was no impact, but it could impact us in the future if we complete any acquisitions with subsequent measurement period adjustments. ASU 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement” The standard clarifies whether a cloud computing arrangement includes a software license. If it does, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses; if not, the customer should account for the arrangement as a service contract. First quarter 2016 The impact of adopting this standard was not material. ASU 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis” The standard eliminates the presumption that a general partner should consolidate a limited partnership. It also modifies the evaluation of whether limited partnerships are variable interest entities or voting interest entities and adds requirements that limited partnerships must meet to qualify as voting interest entities. First quarter 2016 The impact of adopting this standard was not material. ASU 2014-15, “Presentation of Financial Statements- Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern” This standard provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. Fourth quarter 2016 The impact of adopting this standard was not material. Standard Description Date of Adoption Effect on the Financial Statements or Other Significant Matters Standards that are not yet adopted ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory” The standard requires that inventory, excluding inventory measured using last-in, first-out (LIFO) or the retail inventory method, be measured at the lower of cost or net realizable value. First quarter 2017 We do not expect the adoption of this standard to materially impact us. ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships” The standard clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. First quarter 2017 We do not expect the adoption of this standard to materially impact us. ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments” The standard clarifies the requirements for assessing whether a contingent call (put) option that can accelerate the payment of principal on a debt instrument is clearly and closely related to its debt host. First quarter 2017 We do not expect the adoption of this standard to materially impact us. ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)” The standard outlines the principles an entity must apply to measure and recognize revenue for entities that enter into contracts to provide goods or services to their customers. The core principle is that an entity should recognize revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring goods or services to a customer. The amendment also requires more extensive disaggregated revenue disclosures in interim and annual financial statements. First quarter 2018 We are evaluating the impact of this standard on us. Our evaluation process includes a review of our contracts and transaction types across all our business segments. In addition, we are currently evaluating methods of adoption and analyzing the impact of the standard on our internal controls, accounting policies and financial statements and disclosures. ASU 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” The standard requires all equity investments, other than those accounted for using the equity method of accounting or those that result in consolidation of the investee, to be measured at fair value with changes in fair value recognized in net income, eliminates the available-for-sale classification for equity securities with readily determinable fair values and eliminates the cost method for equity investments without readily determinable fair values. First quarter 2018 We are evaluating the impact of this standard on us. ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” The standard clarifies the classification of certain cash receipts and cash payments on the statement of cash flows where diversity in practice has been identified. First quarter 2018 We are evaluating the impact of this standard on us. ASU 2016-02, “Leases (Topic 842)” The standard requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. It also requires qualitative disclosures along with specific quantitative disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing and uncertainty of cash flows arising from leases. First quarter 2019 We are evaluating our current leases and the impact of the standard on our internal controls, accounting policies and financial statements and disclosures. ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” The standard requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented net of the allowance for credit losses to reflect the net carrying value at the amount expected to be collected on the financial asset; and the initial allowance for credit losses for purchased financial assets, including available-for-sale debt securities, to be added to the purchase price rather than being reported as a credit loss expense. First quarter 2020 We are evaluating the impact of this standard on us. ASU 2017-04, “Intangibles- Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” The standard simplifies the subsequent measurement of goodwill by eliminating the requirement to calculate the implied fair value of goodwill under step 2. Instead, an entity will recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value. The standard does not change step zero or step 1 assessments. First quarter 2020 We are evaluating the impact of this standard on us.
Consolidation	Consolidation - Our consolidated financial statements include our accounts and the accounts of our subsidiaries over which we have control or are the primary beneficiary. All significant intercompany balances and transactions have been eliminated in consolidation. Investments in unconsolidated affiliates are accounted for using the equity method if we have the ability to exercise significant influence over operating and financial policies of our investee. Under this method, an investment is carried at its acquisition cost and adjusted each period for contributions made, distributions received and our share of the investee’s comprehensive income. For the investments we account for under the equity method, the premium or excess cost over underlying fair value of net assets is referred to as equity-method goodwill. Impairment of equity investments is recorded when the impairments are other than temporary. These amounts are recorded as investments in unconsolidated affiliates on our accompanying Consolidated Balance Sheets. See Note L for disclosures of our unconsolidated affiliates. Distributions paid to us from our unconsolidated affiliates are classified as operating activities on our Consolidated Statements of Cash Flows until the cumulative distributions exceed our proportionate share of income from the unconsolidated affiliate since the date of our initial investment. The amount of cumulative distributions paid to us that exceeds our cumulative proportionate share of income in each period represents a return of investment and is classified as an investing activity on our Consolidated Statements of Cash Flows.
Use of Estimates	Use of Estimates - 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 amount 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. Items that may be estimated include, but are not limited to, the economic useful life of assets, fair value of assets, liabilities and equity-method investments, provisions for uncollectible accounts receivable, unbilled revenues and cost of goods sold, expenses for services received but for which no invoice has been received, the results of litigation and various other recorded or disclosed amounts. We evaluate these estimates on an ongoing basis using historical experience, consultation with experts and other methods we consider reasonable based on the particular circumstances. Nevertheless, actual results may differ significantly from the estimates. Any effects on our financial position or results of operations from revisions to these estimates are recorded in the period when the facts that give rise to the revision become known.
Fair Value Measurements	Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date. While many of the contracts in our derivative portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist, but the market may be relatively inactive. This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values. For certain transactions, we utilize modeling techniques using NYMEX-settled pricing data and implied forward LIBOR curves. Inputs into our fair value estimates include commodity-exchange prices, over-the-counter quotes, historical correlations of pricing data, data obtained from third-party pricing services and LIBOR and other liquid money-market instrument rates. We validate our valuation inputs with third-party information and settlement prices from other sources, where available. In addition, as prescribed by the income approach, we compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value using interest-rate yields to calculate present-value discount factors derived from LIBOR, Eurodollar futures and the LIBOR interest-rate swaps market. We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions. We consider current market data in evaluating counterparties’, as well as our own, nonperformance risk, net of collateral, by using specific and sector bond yields and monitoring the credit default swap markets. Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material. The fair value of our forward-starting interest-rate swaps are determined using financial models that incorporate the implied forward LIBOR yield curve for the same period as the future interest-rate swap settlements. Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below: • Level 1 - fair value measurements are based on unadjusted quoted prices for identical securities in active markets, including NYMEX-settled prices. These balances are comprised predominantly of exchange-traded derivative contracts for natural gas and crude oil. • Level 2 - fair value measurements are based on significant observable pricing inputs, such as NYMEX-settled prices for natural gas and crude oil, and financial models that utilize implied forward LIBOR yield curves for interest-rate swaps. • Level 3 - fair value measurements are based on inputs that may include one or more unobservable inputs, including internally developed natural gas basis and NGL price curves that incorporate observable and unobservable market data from broker quotes, third-party pricing services, market volatilities derived from the most recent NYMEX close spot prices and forward LIBOR curves, and adjustments for the credit risk of our counterparties. We corroborate the data on which our fair value estimates are based using our market knowledge of recent transactions, analysis of historical correlations and validation with independent broker quotes. These balances categorized as Level 3 are comprised of derivatives for natural gas and NGLs. We do not believe that our Level 3 fair value estimates have a material impact on our results of operations, as the majority of our derivatives are accounted for as hedges for which ineffectiveness has not been material. Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety. See Note C for discussion of our fair value measurements.
Cash and Cash Equivalents	Cash and Cash Equivalents - Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have original maturities of three months or less.
Revenue Recognition	Revenue Recognition - Our reportable segments recognize revenue when services are rendered or product is delivered. Our Natural Gas Gathering and Processing segment records revenues when natural gas is gathered or processed through our facilities. Our Natural Gas Liquids segment records revenues based upon contracted services and volumes exchanged or stored under service agreements in the period services are provided. A portion of our revenues for our Natural Gas Pipelines segment and our Natural Gas Liquids segment are recognized based upon contracted capacity and contracted volumes transported and stored under service agreements in the period services are provided. We disaggregate revenue on the Consolidated Statements of Income as follows: • Commodity sales - Commodity sales represent the sale of NGLs, condensate and residue natural gas. We generally purchase a supplier’s raw natural gas or unfractionated NGLs, which we process into marketable commodities and condensate, then we sell these commodities and condensate to downstream customers. Commodity sales are recognized upon delivery or title transfer to the customer, when revenue recognition criteria are met. • Service revenue - Service revenue represents the fees generated from the performance of our services. We enter into a variety of contract types that provide commodity sales and service revenue. We provide services primarily under the following types of contracts: • Fee-based - Under fee-based arrangements, we receive a fee or fees for one or more of the following services: gathering, compression, processing, transmission and storage of natural gas; and gathering, transportation, fractionation and storage of NGLs. The revenue we earn from these arrangements generally is directly related to the volume of natural gas and NGLs that flow through our systems and facilities, and is not normally directly dependent on commodity prices. However, to the extent a sustained decline in commodity prices results in a decline in volumes, our revenues from these arrangements would be reduced. In addition, many of our arrangements provide for fixed fee, minimum volume or firm demand charges. Fee-based arrangements are reported as service revenue on the Consolidated Statements of Income. • Percent-of-proceeds - Under POP arrangements in our Natural Gas Gathering and Processing segment, we generally purchase the producer’s raw natural gas which we process into natural gas and natural gas liquids, then we sell these commodities and condensate to downstream customers. We remit sales proceeds to the producer according to the contractual terms and retain our portion. Typically, our POP arrangements also include a fee-based component. In many cases, our Natural Gas Gathering and Processing segment provides services under contracts that contain a combination of the arrangements described above. When services are provided (in addition to raw natural gas purchased) under POP with fee contracts, we record such fees as service revenue on the Consolidated Statements of Income. The terms of our contracts vary based on natural gas quality conditions, the competitive environment when the contracts are signed and customer requirements.
Cost of Sales and Fuel	Cost of Sales and Fuel - Cost of sales and fuel primarily includes (i) the cost of purchased commodities, including NGLs, natural gas and condensate, (ii) fees incurred for third-party transportation, fractionation and storage of commodities, and (iii) fuel and power costs incurred to operate our own facilities that gather, process, transport and store commodities.
Operations and Maintenance	Operations and Maintenance - Operations and maintenance primarily includes (i) payroll and benefit costs, (ii) third-party costs for operations, maintenance and integrity management, regulatory compliance and environmental and safety, and (iii) other business related service costs.
Accounts Receivable	Accounts Receivable - Accounts receivable represent valid claims against nonaffiliated customers for products sold or services rendered, net of allowances for doubtful accounts. We assess the creditworthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of collateral, when appropriate. Outstanding customer receivables are reviewed regularly for possible nonpayment indicators, and allowances for doubtful accounts are recorded based upon management’s estimate of collectability at each balance sheet date. At December 31, 2016 and 2015 , our allowance for doubtful accounts was not material.
Inventory	Inventory - The values of current natural gas and NGLs in storage are determined using the lower of weighted-average cost or market method. Noncurrent natural gas and NGLs are classified as property and valued at cost. Materials and supplies are valued at average cost.
Commodity Imbalances	Commodity Imbalances - Commodity imbalances represent amounts payable or receivable for NGL exchange contracts and natural gas pipeline imbalances and are valued at market prices. Under the majority of our NGL exchange agreements, we physically receive volumes of unfractionated NGLs, including the risk of loss and legal title to such volumes, from the exchange counterparty. In turn, we deliver NGL products back to the customer and charge them gathering, fractionation and transportation fees. To the extent that the volumes we receive under such agreements differ from those we deliver, we record a net exchange receivable or payable position with the counterparties. These net exchange receivables and payables are settled with movements of NGL products rather than with cash. Natural gas pipeline imbalances are settled in cash or in-kind, subject to the terms of the pipelines’ tariffs or by agreement.
Derivatives and Risk Management	Derivatives and Risk Management - We utilize derivatives to reduce our market-risk exposure to commodity price and interest-rate fluctuations and to achieve more predictable cash flows. We record all derivative instruments at fair value, with the exception of normal purchases and normal sales transactions that are expected to result in physical delivery. Commodity price and interest-rate volatility may have a significant impact on the fair value of derivative instruments as of a given date. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it. The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements: Recognition and Measurement Accounting Treatment Balance Sheet Income Statement Normal purchases and normal sales - Fair value not recorded - Change in fair value not recognized in earnings Mark-to-market - Recorded at fair value - Change in fair value recognized in earnings Cash flow hedge - Recorded at fair value - Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings - Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) - Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated other comprehensive income (loss) into earnings when the forecasted transaction affects earnings Fair value hedge - Recorded at fair value - The gain or loss on the derivative instrument is recognized in earnings - Change in fair value of the hedged item is recorded as an adjustment to book value - Change in fair value of the hedged item is recognized in earnings To reduce our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter into futures, forward purchases and sales, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate. Interest-rate swaps are used from time to time to manage interest-rate risk. Under certain conditions, we designate our derivative instruments as a hedge of exposure to changes in fair values or cash flows. We formally document all relationships between hedging instruments and hedged items, as well as risk-management objectives and strategies for undertaking various hedge transactions, and methods for assessing and testing correlation and hedge ineffectiveness. We specifically identify the forecasted transaction that has been designated as the hedged item in a cash flow hedge relationship. We assess the effectiveness of hedging relationships quarterly by performing an effectiveness analysis on our fair value and cash flow hedging relationships to determine whether the hedge relationships are highly effective on a retrospective and prospective basis. We also document our normal purchases and normal sales transactions that we expect to result in physical delivery and that we elect to exempt from derivative accounting treatment. The realized revenues and purchase costs of our derivative instruments not considered held for trading purposes and derivatives that qualify as normal purchases or normal sales that are expected to result in physical delivery are reported on a gross basis. Cash flows from futures, forwards and swaps that are accounted for as hedges are included in the same category as the cash flows from the related hedged items in our Consolidated Statements of Cash Flows. See Notes C and D for more discussion of our fair value measurements and risk-management and hedging activities using derivatives.
Property, Plant and Equipment	Property, Plant and Equipment - Our properties are stated at cost, including AFUDC and capitalized interest. In some cases, the cost of regulated property retired or sold, plus removal costs, less salvage, is charged to accumulated depreciation. Gains and losses from sales or transfers of nonregulated properties or an entire operating unit or system of our regulated properties are recognized in income. Maintenance and repairs are charged directly to expense. The interest portion of AFUDC and capitalized interest represent the cost of borrowed funds used to finance construction activities for regulated and nonregulated projects, respectively. We capitalize interest costs during the construction or upgrade of qualifying assets. These costs are recorded as a reduction to interest expense. The equity portion of AFUDC represents the capitalization of the estimated average cost of equity used during the construction of major projects and is recorded in the cost of our regulated properties and as a credit to the allowance for equity funds used during construction. Our properties are depreciated using the straight-line method over their estimated useful lives. Generally, we apply composite depreciation rates to functional groups of property having similar economic circumstances. We periodically conduct depreciation studies to assess the economic lives of our assets. For our regulated assets, these depreciation studies are completed as a part of our rate proceedings or tariff filings, and the changes in economic lives, if applicable, are implemented prospectively when the new rates are billed. For our nonregulated assets, if it is determined that the estimated economic life changes, the changes are made prospectively. Changes in the estimated economic lives of our property, plant and equipment could have a material effect on our financial position or results of operations. Property, plant and equipment on our Consolidated Balance Sheets includes construction work in process for capital projects that have not yet been placed in service and therefore are not being depreciated. Assets are transferred out of construction work in process when they are substantially complete and ready for their intended use. See Note E for disclosures of our property, plant and equipment.
Impairment of Goodwill and Long-Lived Assets, including Intangible Assets	Impairment of Goodwill and Long-Lived Assets, Including Intangible Assets - We assess our goodwill for impairment at least annually on July 1, unless events or changes in circumstances indicate an impairment may have occurred before that time. As the commodity price environment has remained relatively low since 2015, we elected to perform a quantitative assessment, or Step 1 analysis, to test our goodwill for impairment. The assessment included our current commodity price assumptions, expected contractual terms, anticipated operating costs and volume estimates. Our goodwill impairment analysis performed as of July 1, 2016, did not result in an impairment charge nor did our analysis reflect any reporting units at risk. In each reporting unit, the fair value substantially exceeded the carrying value. Subsequent to that date, no event has occurred indicating that the implied fair value of each of our reporting units is less than the carrying value of its net assets. As part of our impairment test, we may first assess qualitative factors (including macroeconomic conditions, industry and market considerations, cost factors and overall financial performance) to determine whether it is more likely than not that the fair value of each of our reporting units is less than its carrying amount. If further testing is necessary or a quantitative test is elected, we perform a two-step impairment test for goodwill. In the first step, an initial assessment is made by comparing the fair value of a reporting unit with its book value, including goodwill. If the fair value is less than the book value, an impairment is indicated, and we must perform a second test to measure the amount of the impairment. In the second test, we calculate the implied fair value of the goodwill by deducting the fair value of all tangible and intangible net assets of the reporting unit from the fair value determined in step one of the assessment. If the carrying value of the goodwill exceeds the implied fair value of the goodwill, we will record an impairment charge. 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. We assess our long-lived assets, including intangible assets with finite useful lives, 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. For the investments we account for under the equity method, the impairment test 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 reevaluate the amount at which we carry our equity-method investments to determine whether current events or circumstances warrant adjustments to our carrying values. See Notes E , F and L for our long-lived assets, goodwill and intangible assets and investments in unconsolidated affiliates disclosures.
Regulation	Regulation - Our intrastate natural gas transmission and natural gas liquids pipelines are subject to the rate regulation and accounting requirements of the OCC, KCC, RRC and various municipalities in Texas. Our interstate natural gas and natural gas liquids pipelines are subject to regulation by the FERC. In Kansas and Texas, natural gas storage may be regulated by the state and the FERC for certain types of services. Accordingly, portions of our Natural Gas Liquids and Natural Gas Pipelines segments follow the accounting and reporting guidance for regulated operations. In our Consolidated Financial Statements and our Notes to Consolidated Financial Statements, regulated operations are defined pursuant to Financial Accounting Standards Board’s (FASB) Accounting Standards Codification (ASC) 980, Regulated Operations. During the rate-making process for certain of our assets, regulatory authorities set the framework for what we can charge customers for our services and establish the manner that our costs are accounted for, including allowing us to defer recognition of certain costs and permitting recovery of the amounts through rates over time as opposed to expensing such costs as incurred. Certain examples of types of regulatory guidance include costs for fuel and losses, acquisition costs, contributions in aid of construction, charges for depreciation, and gains or losses on disposition of assets. This allows us to stabilize rates over time rather than passing such costs on to the customer for immediate recovery. Actions by regulatory authorities could have an effect on the amount recovered from rate payers. Any difference in the amount recoverable and the amount deferred is recorded as income or expense at the time of the regulatory action. A write-off of regulatory assets and costs not recovered may be required if all or a portion of the regulated operations have rates that are no longer: • established by independent, third-party regulators; • designed to recover the specific entity’s costs of providing regulated services; and • set at levels that will recover our costs when considering the demand and competition for our services. At December 31, 2016 and 2015 , we recorded regulatory assets of approximately $5.5 million and $5.8 million , respectively, which are currently being recovered and are expected to be recovered from our customers. Regulatory assets are being recovered as a result of approved rate proceedings over varying time periods up to 50 years. These assets are reflected in other assets on our Consolidated Balance Sheets.
Income Taxes	Income Taxes - We are not a taxable entity for federal income tax purposes. As such, we do not directly pay federal income tax. For our operations in Texas, we are subject to the Texas franchise tax, which is included in income tax expense in our consolidated statements of income. Our taxable income or loss, which may vary substantially from the net income or loss reported in our Consolidated Statements of Income, is included in the federal income tax returns of each partner. The aggregate difference in the basis of our net assets for financial and income tax purposes cannot be readily determined, as we do not have access to all information about each partner’s tax attributes related to us. Our corporate subsidiaries are required to pay federal and state income taxes. Deferred income taxes are provided for the difference between the financial statement and income tax basis of assets and liabilities and carryforward items based on income tax laws and rates existing at the time the temporary differences are expected to reverse. Generally, the effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date of the rate change. For regulated companies, the effect on deferred tax assets and liabilities of a change in tax rates is recorded as regulatory assets and regulatory liabilities in the period that includes the enactment date, if, as a result of an action by a regulator, it is probable that the effect of the change in tax rates will be recovered from or returned to customers through future rates. We utilize a more-likely-than-not recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position that is taken or expected to be taken in a tax return. We reflect penalties and interest as part of income tax expense as they become applicable for tax provisions that do not meet the more-likely-than-not recognition threshold and measurement attribute. During 2016, 2015 and 2014 , our tax positions did not require an establishment of a material reserve. We file numerous consolidated and separate income tax returns with federal tax authorities of the United States along with the tax authorities of several states. There are no United States federal audits or statute waivers at this time. See Note K for additional discussion of income taxes.
Asset Retirement Obligations	Asset Retirement Obligations - Asset retirement obligations represent legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset. Certain of our natural gas gathering and processing, natural gas liquids and natural gas pipeline facilities are subject to agreements or regulations that give rise to our asset retirement obligations for removal or other disposition costs associated with retiring the assets in place upon the discontinued use of the assets. We recognize the fair value of a liability for an asset retirement obligation in the period when it is incurred if a reasonable estimate of the fair value can be made. We are not able to estimate reasonably the fair value of the asset retirement obligations for portions of our assets, primarily certain pipeline assets, because the settlement dates are indeterminable given our expected continued use of the assets with proper maintenance. We expect our pipeline assets, for which we are unable to estimate reasonably the fair value of the asset retirement obligation, will continue in operation as long as supply and demand for natural gas and natural gas liquids exists. Based on the widespread use of natural gas for heating and cooking activities for residential users and electric-power generation for commercial users, as well as use of natural gas liquids by the petrochemical industry, we expect supply and demand to exist for the foreseeable future. For our assets that we are able to make an estimate, the fair value of the liability is added to the carrying amount of the associated asset, and this additional carrying amount is depreciated over the life of the asset. The liability is accreted at the end of each period through charges to operating expense. If the obligation is settled for an amount other than the carrying amount of the liability, we will recognize a gain or loss on settlement. The depreciation and accretion expense are immaterial to our consolidated financial statements. In accordance with long-standing regulatory treatment, we collect, through rates, the estimated costs of removal on certain regulated properties through depreciation expense, with a corresponding credit to accumulated depreciation and amortization. These removal costs collected through rates include legal and nonlegal removal obligations; however, the amounts collected in excess of the asset removal costs incurred are accounted for as a regulatory liability for financial reporting purposes. Historically, the regulatory authorities that have jurisdiction over our regulated operations have not required us to quantify this amount; rather, these costs are addressed prospectively in depreciation rates and are set in each general rate order. We have made an estimate of our regulatory liability using current rates since the last general rate order in each of our jurisdictions; however, for financial reporting purposes, significant uncertainty exists regarding the ultimate disposition of this regulatory liability pending, among other issues, clarification of regulatory intent. We continue to monitor regulatory requirements, and the liability may be adjusted as more information is obtained.
Contingencies	Contingencies - Our accounting for contingencies covers a variety of business activities, including contingencies for legal and environmental exposures. We accrue these contingencies when our assessments indicate that it is probable that a liability has been incurred or an asset will not be recovered and an amount can be estimated reasonably. We expense legal fees as incurred and base our legal liability estimates on currently available facts and our estimates of the ultimate outcome or resolution. Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of a remediation feasibility study. Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is deemed probable. Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position or results of operations, and our expenditures related to environmental matters had no material effect on earnings or cash flows during 2016, 2015 and 2014 . Actual results may differ from our estimates resulting in an impact, positive or negative, on earnings. See Note N for additional discussion of contingencies.

DEBT DEBT (Policies)

DEBT DEBT (Policies)	12 Months Ended
	Dec. 31, 2016
Debt Instrument [Line Items]
Debt Policy	We amortize premiums, discounts and expenses incurred in connection with the issuance of long-term debt consistent with the terms of the respective debt instrument.

EQUITY EQUITY (Policies)

EQUITY EQUITY (Policies)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Partnership agreement	Partnership Agreement - Available cash, as defined in our Partnership Agreement generally will be distributed to our general partner and limited partners according to their partnership percentages of 2 percent and 98 percent, respectively. Our general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter. Under the incentive distribution provisions, as set forth in our Partnership Agreement, our general partner receives: • 15 percent of amounts distributed in excess of $0.3025 per unit; • 25 percent of amounts distributed in excess of $0.3575 per unit; and • 50 percent of amounts distributed in excess of $0.4675 per unit.

RELATED-PARTY TRANSACTIONS Rela

RELATED-PARTY TRANSACTIONS Related Party Transactions (Policies)	12 Months Ended
	Dec. 31, 2016
Related Party Transaction [Line Items]
Allocation of Costs Incurred by Related Party, Policy [Policy Text Block]	ONEOK and its affiliates provide a variety of services to us under the Services Agreement, including cash management and financial services, employee benefits provided through ONEOK’s benefit plans, legal and administrative services, insurance and office space leased in ONEOK’s headquarters building and other field locations. Where costs are incurred specifically on behalf of one of our affiliates, the costs are billed directly to us by ONEOK. In other situations, the costs may be allocated to us through a variety of methods, depending upon the nature of the expense and activities. Beginning in the second quarter 2014, ONEOK allocates substantially all of its general overhead costs to us as a result of ONEOK’s separation of its natural gas distribution business and the wind down of its energy services business in the first quarter 2014. For the first quarter 2014, it is not practicable to determine what these general overhead costs would have been on a stand-alone basis. All costs directly charged or allocated to us are included in our Consolidated Statements of Income.

LIMITED PARTNERS' NET INCOME 31

LIMITED PARTNERS' NET INCOME PER UNIT LIMITED PARTNERS' NET INCOME PER UNIT (Policies)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Earnings Per Share, Policy [Policy Text Block]	Limited partners’ net income per unit is computed by dividing net income attributable to ONEOK Partners, L.P., after deducting the general partner’s allocation as discussed below, by the weighted-average number of outstanding limited partner units, which includes our common and Class B limited partner units. Because ONEOK has conditionally waived its right to increased quarterly distributions, until it gives 90 days notice of the withdrawal of the waiver, currently each Class B and common unit share equally in the earnings of the Partnership, and neither has any liquidation or other preferences. ONEOK Partners GP owns the entire 2 percent general partnership interest in us, which entitles it to incentive distribution rights that provide for an increasing proportion of cash distributions from the Partnership as the distributions made to limited partners increase above specified levels. For purposes of our calculation of limited partners’ net income per unit, net income attributable to ONEOK Partners, L.P. is allocated to the general partner as follows: (i) an amount based upon the 2 percent general partner interest in net income attributable to ONEOK Partners, L.P.; and (ii) the amount of the general partner’s incentive distribution rights based on the total cash distributions declared for the period. The amount of incentive distributions allocated to our general partner totaled $402.2 million , $382.8 million and $326.0 million for 2016, 2015 and 2014 , respectively. The terms of our Partnership Agreement limit the general partner’s incentive distribution to the amount of available cash calculated for the period. As such, incentive distribution rights are not allocated on undistributed earnings. For additional information regarding our general partner’s incentive distribution rights, see “Partnership Agreement” in Note H .

ACQUISITIONS ACQUISITIONS (Poli

ACQUISITIONS ACQUISITIONS (Policies)	12 Months Ended
	Dec. 31, 2016
West Texas LPG Acquisition [Member]
Business Acquisition [Line Items]
Business Combinations Policy [Policy Text Block]	We accounted for the West Texas LPG acquisition as a business combination which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition-date fair values.

SEGMENTS SEGMENTS (Policies)

SEGMENTS SEGMENTS (Policies)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Accounting Policy [Text Block]	The accounting policies of the segments are described in Note A . Our chief operating decision-maker reviews the financial performance of each of our three segments, as well as the financial performance of the Partnership as a whole, on a regular basis. Beginning in 2016, adjusted EBITDA by segment is utilized in this evaluation. We believe this 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 are commonly employed by financial analysts and others to evaluate our financial performance and to compare financial performance among companies in our industry. Adjusted EBITDA for each segment is defined as net income adjusted for interest expense, depreciation and amortization, noncash impairment charges, income taxes, allowance for equity funds used during construction and other noncash items. This calculation may not be comparable with similarly titled measures of other companies. Prior period segment disclosures have been recast to reflect this change. As a result of ONEOK’s separation of its natural gas distribution business into a stand-alone publicly traded company called ONE Gas on January 31, 2014, transactions with ONE Gas subsequent to the separation are reflected as sales to unaffiliated customers.

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Recurring Fair Value Measurements	Recurring Fair Value Measurements - The following tables set forth our recurring fair value measurements for the periods indicated: December 31, 2016 Level 1 Level 2 Level 3 Total - Gross Netting (a) Total - Net (b) ( Thousands of dollars ) Derivative assets Commodity contracts Financial contracts $ 1,147 $ — $ 4,564 $ 5,711 $ (4,760 ) $ 951 Interest-rate contracts — 47,457 — 47,457 — 47,457 Total derivative assets $ 1,147 $ 47,457 $ 4,564 $ 53,168 $ (4,760 ) $ 48,408 Derivative liabilities Commodity contracts Financial contracts $ (31,458 ) $ — $ (24,861 ) $ (56,319 ) $ 56,319 $ — Physical contracts — — (3,022 ) (3,022 ) — (3,022 ) Interest-rate contracts — (12,795 ) — (12,795 ) — (12,795 ) Total derivative liabilities $ (31,458 ) $ (12,795 ) $ (27,883 ) $ (72,136 ) $ 56,319 $ (15,817 ) (a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2016 , we held no cash and posted $67.7 million of cash with various counterparties, including $51.6 million of cash collateral that is offsetting derivative net liability positions under master-netting arrangements in the table above. The remaining $16.1 million of cash collateral in excess of derivative net liability positions is included in other current assets in our Consolidated Balance Sheets. (b) - Included in other current assets, other assets or other current liabilities in our Consolidated Balance Sheets. December 31, 2015 Level 1 Level 2 Level 3 Total - Gross Netting (a) Total - Net (b) ( Thousands of dollars ) Derivative assets Commodity contracts Financial contracts $ 38,921 $ — $ 7,253 $ 46,174 $ (42,414 ) $ 3,760 Physical contracts — — 3,591 3,591 — 3,591 Total derivative assets $ 38,921 $ — $ 10,844 $ 49,765 $ (42,414 ) $ 7,351 Derivative liabilities Commodity contracts Financial contracts $ (4,513 ) $ — $ (3,513 ) $ (8,026 ) $ 8,026 $ — Interest-rate contracts — (9,936 ) — (9,936 ) — (9,936 ) Total derivative liabilities $ (4,513 ) $ (9,936 ) $ (3,513 ) $ (17,962 ) $ 8,026 $ (9,936 ) (a) - Derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities when a legally enforceable master-netting arrangement exists between the counterparty to a derivative contract and us. At December 31, 2015 , we held $34.4 million of cash from various counterparties that is offsetting derivative net asset positions in the table above under master-netting arrangements and had no cash collateral posted. (b) - Included in other current assets or other current liabilities in our Consolidated Balance Sheets.
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: Years Ended December 31, Derivative Assets (Liabilities) 2016 2015 ( Thousands of dollars ) Net assets (liabilities) at beginning of period $ 7,331 $ 9,285 Total realized/unrealized gains (losses): Included in earnings (a) (320 ) 216 Included in other comprehensive income (loss) (30,330 ) (2,170 ) Net assets (liabilities) at end of period $ (23,319 ) $ 7,331 (a) - Included in commodity sales revenues in our Consolidated Statements of Income.

RISK MANAGEMENT AND HEDGING A35

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in Statement of Financial Position	Fair Values of Derivative Instruments - The following table sets forth the fair values of our derivative instruments presented on a gross basis for the periods indicated: December 31, 2016 December 31, 2015 Location in our Consolidated Balance Sheets Assets (Liabilities) Assets (Liabilities) ( Thousands of dollars ) Derivatives designated as hedging instruments Commodity contracts Financial contracts Other current assets/other current liabilities $ 1,155 $ (49,938 ) $ 39,255 $ (1,440 ) Other assets/deferred credits and other liabilities 210 (2,142 ) — — Physical contracts Other current assets/other current liabilities — (3,022 ) 3,591 — Interest-rate contracts Other assets/other current liabilities 47,457 (12,795 ) — (9,936 ) Total derivatives designated as hedging instruments 48,822 (67,897 ) 42,846 (11,376 ) Derivatives not designated as hedging instruments Commodity contracts Financial contracts Other current assets/other current liabilities 4,346 (4,239 ) 6,919 (6,586 ) Total derivatives not designated as hedging instruments 4,346 (4,239 ) 6,919 (6,586 ) Total derivatives $ 53,168 $ (72,136 ) $ 49,765 $ (17,962 )
Schedule of Notional Quantities for Derivative Instruments	Notional Quantities for Derivative Instruments - The following table sets forth the notional quantities for derivative instruments held for the periods indicated: December 31, 2016 December 31, 2015 Contract Type Purchased/ Payor Sold/ Receiver Purchased/ Payor Sold/ Receiver Derivatives designated as hedging instruments: Cash flow hedges Fixed price -Natural gas ( Bcf ) Futures and swaps — (38.4 ) — (27.1 ) -Natural gas ( Bcf ) Put options 49.5 — — — -Crude oil and NGLs ( MMBbl ) Futures, forwards and swaps — (3.6 ) — (2.3 ) Basis -Natural gas ( Bcf ) Futures and swaps — (38.4 ) — (27.1 ) Interest-rate contracts ( Millions of dollars ) Swaps $ 2,150.0 $ — $ 400.0 $ — Derivatives not designated as hedging instruments: Fixed price -Natural gas ( Bcf ) Futures and swaps 0.4 — — — -NGLs ( MMBbl ) Futures, forwards and swaps 0.5 (0.7 ) 0.6 (0.6 ) Basis -Natural gas ( Bcf ) Futures and swaps 0.4 — — —
Schedule of Cash Flow Hedges in Other Comprehensive Income (Loss)	The following table sets forth the unrealized effect of cash flow hedges recognized in other comprehensive income (loss) for the periods indicated: Derivatives in Cash Flow Hedging Relationships Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Commodity contracts $ (78,513 ) $ 70,065 $ 32,354 Interest-rate contracts 42,761 (22,565 ) (96,993 ) Total unrealized gain (loss) recognized in other comprehensive income (loss) on derivatives (effective portion) $ (35,752 ) $ 47,500 $ (64,639 )
Schedule of Derivative Instruments, Gain (loss) of Statement of Financial Performance	The following table sets forth the effect of cash flow hedges in our Consolidated Statements of Income for the periods indicated: Derivatives in Cash Flow Hedging Relationships Location of Gain (Loss) Reclassified from Accumulated Other Comprehensive Loss into Net Income (Effective Portion) Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Commodity contracts Commodity sales revenues $ 26,422 $ 81,089 $ (21,052 ) Interest-rate contracts Interest expense (15,705 ) (14,055 ) (10,601 ) Total gain (loss) reclassified from accumulated other comprehensive loss into net income on derivatives (effective portion) $ 10,717 $ 67,034 $ (31,653 )

PROPERTY, PLANT AND EQUIPMENT36

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment by Property Type	The following table sets forth our property, plant and equipment by property type, for the periods indicated: Estimated Useful Lives (Years) December 31, December 31, ( Thousands of dollars ) Nonregulated Gathering pipelines and related equipment 5 to 40 $ 3,352,963 $ 2,961,388 Processing and fractionation and related equipment 3 to 40 3,831,966 3,627,062 Storage and related equipment 5 to 54 558,695 510,820 Transmission pipelines and related equipment 5 to 54 689,804 598,375 General plant and other 2 to 60 264,049 226,858 Construction work in process — 371,337 690,179 Regulated Storage and related equipment 5 to 25 13,524 22,085 Natural gas transmission pipelines and related equipment 5 to 77 1,345,740 1,325,235 Natural gas liquids transmission pipelines and related equipment 5 to 88 4,309,341 4,208,121 General plant and other 2 to 50 54,643 53,962 Construction work in process — 62,634 83,461 Property, plant and equipment 14,854,696 14,307,546 Accumulated depreciation and amortization - nonregulated (1,526,400 ) (1,290,931 ) Accumulated depreciation and amortization - regulated (865,604 ) (759,824 ) Net property, plant and equipment $ 12,462,692 $ 12,256,791
Average Depreciation Rates for Regulated Property	The average depreciation rates for our regulated property are set forth, by segment, in the following table for the periods indicated: Years Ended December 31, 2016 2015 2014 Natural Gas Liquids 1.9% 1.9% 2.0% Natural Gas Pipelines 2.1% 2.1% 2.1%

GOODWILL AND INTANGIBLE ASSET37

GOODWILL AND INTANGIBLE ASSETS (Tables)	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill by Segment	Goodwill - The following table sets forth our goodwill, by segment, for the periods indicated: December 31, 2016 December 31, 2015 ( Thousands of dollars ) Natural Gas Gathering and Processing $ 112,141 $ 112,141 Natural Gas Liquids 247,566 247,566 Natural Gas Pipelines 129,011 129,011 Total goodwill $ 488,718 $ 488,718
Gross Carrying Amount and Accumulated Amortization of Intangible Assets	The following table reflects the gross carrying amount and accumulated amortization of intangible assets for the periods presented: December 31, December 31, ( Thousands of dollars ) Gross intangible assets $ 426,068 $ 426,068 Accumulated amortization (101,809 ) (89,909 ) Net intangible assets $ 324,259 $ 336,159

DEBT (Tables)

DEBT (Tables)	12 Months Ended
	Dec. 31, 2016
Long-term Debt, Unclassified [Abstract]
Long-term debt	The following table sets forth our debt for the periods indicated: December 31, December 31, ( Thousands of dollars ) ONEOK Partners Borrowings outstanding under the Partnership Credit Agreement at 1.60% as of December 31, 2015 (a) $ — $ 300,000 Commercial paper outstanding, bearing a weighted-average interest rate of 1.27% and 1.23%, respectively 1,110,277 246,340 Senior unsecured obligations: $650,000 at 3.25% due 2016 — 650,000 $450,000 at 6.15% due 2016 — 450,000 $400,000 at 2.0% due 2017 400,000 400,000 $425,000 at 3.2% due 2018 425,000 425,000 $1,000,000 term loan, variable rate, due 2019 1,000,000 — $500,000 at 8.625% due 2019 500,000 500,000 $300,000 at 3.8% due 2020 300,000 300,000 $900,000 at 3.375 % due 2022 900,000 900,000 $425,000 at 5.0 % due 2023 425,000 425,000 $500,000 at 4.9 % due 2025 500,000 500,000 $600,000 at 6.65% due 2036 600,000 600,000 $600,000 at 6.85% due 2037 600,000 600,000 $650,000 at 6.125% due 2041 650,000 650,000 $400,000 at 6.2% due 2043 400,000 400,000 Guardian Pipeline Average 7.88% due 2022 44,257 51,907 Total debt 7,854,534 7,398,247 Unamortized debt issuance costs and discounts (45,300 ) (48,945 ) Current maturities of long-term debt (407,650 ) (107,650 ) Short-term borrowings (b) (1,110,277 ) (546,340 ) Long-term debt $ 6,291,307 $ 6,695,312 (a) - We had $14 million of letters of credit issued at December 31, 2016 and 2015. (b) - Individual issuances of commercial paper under our $2.4 billion commercial paper program generally mature in 90 days or less. However, these issuances are supported by and reduce the borrowing capacity under our Partnership Credit Agreement.
Aggregate maturities of long-term debt outstanding	The aggregate maturities of long-term debt outstanding as of December 31, 2016, for the years 2017 through 2021 are shown below: ONEOK Partners Guardian Pipeline Total ( Millions of dollars ) 2017 $ 400.0 $ 7.7 $ 407.7 2018 $ 425.0 $ 7.7 $ 432.7 2019 $ 1,500.0 $ 7.7 $ 1,507.7 2020 $ 300.0 $ 7.7 $ 307.7 2021 $ — $ 7.7 $ 7.7

EQUITY (Tables)

EQUITY (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Quarterly cash distribution declared and paid on common and Class B units	Cash Distributions - The following table sets forth the quarterly cash distribution declared and paid on each of our common and Class B units during the periods indicated: Declared for Quarter Ending Distribution Per Unit Date Declared Date Paid December 31, 2016 $ 0.790 January 18, 2017 February 14, 2017 September 30, 2016 $ 0.790 October 19, 2016 November 14, 2016 June 30, 2016 $ 0.790 July 28, 2016 August 14, 2016 March 31, 2016 $ 0.790 April 21, 2016 May 13, 2016 December 31, 2015 $ 0.790 January 21, 2016 February 12, 2016 September 30, 2015 $ 0.790 October 21, 2015 November 13, 2015 June 30, 2015 $ 0.790 July 23, 2015 August 14, 2015 March 31, 2015 $ 0.790 April 16, 2015 May 15, 2015 December 31, 2014 $ 0.790 January 15, 2015 February 13, 2015 September 30, 2014 $ 0.775 October 23, 2014 November 14, 2014 June 30, 2014 $ 0.760 July 25, 2014 August 14, 2014 March 31, 2014 $ 0.745 April 18, 2014 May 15, 2014 December 31, 2013 $ 0.730 January 16, 2014 February 14, 2014
Schedule of distributions made to general or limited partner	The following table shows our distributions paid during the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands, except per unit amounts ) Distribution per unit $ 3.16 $ 3.16 $ 3.01 General partner distributions $ 26,640 $ 24,610 $ 21,044 Incentive distributions 402,152 371,500 304,999 Distributions to general partner 428,792 396,110 326,043 Limited partner distributions to ONEOK 361,292 310,230 279,292 Limited partner distributions to other unitholders 541,919 524,135 446,910 Total distributions paid $ 1,332,003 $ 1,230,475 $ 1,052,245
Schedule of distributions declared to general or limited partner	Distributions are declared and paid within 45 days of the completion of each quarter. The following table shows our distributions declared for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands, except per unit amounts ) Distribution per unit $ 3.16 $ 3.16 $ 3.07 General partner distributions $ 26,640 $ 25,356 $ 22,109 Incentive distributions 402,152 382,759 326,022 Distributions to general partner 428,792 408,115 348,131 Limited partner distributions to ONEOK 361,292 327,250 284,860 Limited partner distributions to other unitholders 541,919 532,405 472,466 Total distributions declared $ 1,332,003 $ 1,267,770 $ 1,105,457

RELATED-PARTY TRANSACTIONS (Tab

RELATED-PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Transactions with related parties	The following table sets forth the transactions with related parties for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Revenues $ — $ — $ 53,526 Expenses Cost of sales and fuel $ — $ — $ 10,835 Operating expenses 388,142 368,346 330,541 Total expenses $ 388,142 $ 368,346 $ 341,376

ACCUMULATED OTHER COMPREHENSI41

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The following table sets forth the balance in accumulated other comprehensive loss for the periods indicated: Unrealized Gains Unrealized Gains Accumulated ( Thousands of dollars ) January 1, 2015 $ (91,823 ) $ — $ (91,823 ) Other comprehensive income (loss) before reclassifications 47,500 (1,925 ) 45,575 Amounts reclassified from accumulated other comprehensive loss (67,034 ) — (67,034 ) Other comprehensive income (loss) attributable to ONEOK Partners (19,534 ) (1,925 ) (21,459 ) December 31, 2015 (111,357 ) (1,925 ) (113,282 ) Other comprehensive income (loss) before reclassifications (35,752 ) (1,838 ) (37,590 ) Amounts reclassified from accumulated other comprehensive loss (10,717 ) 63 (10,654 ) Other comprehensive income (loss) attributable to ONEOK Partners (46,469 ) (1,775 ) (48,244 ) December 31, 2016 $ (157,826 ) $ (3,700 ) $ (161,526 )
Disclosure of Reclassification Amount [Text Block]	The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our Consolidated Statements of Income for the periods indicated: Details about Accumulated Other Comprehensive Loss Components Years Ended December 31, Affected Line Item in the Consolidated Statements of Income 2016 2015 2014 ( Thousands of dollars ) Unrealized gains (losses) on risk-management assets/liabilities Commodity contracts $ 26,422 $ 81,089 $ (21,052 ) Commodity sales revenues Interest-rate contracts (15,705 ) (14,055 ) (10,601 ) Interest expense $ 10,717 $ 67,034 $ (31,653 ) Net income attributable to ONEOK Partners Unrealized Gains (Losses) on Risk-Management Assets/Liabilities of Unconsolidated Affiliates Interest-rate contracts $ (63 ) $ — $ — Equity in net earnings from investments Total reclassifications for the period attributable to ONEOK Partners $ 10,654 $ 67,034 $ (31,653 ) Net income attributable to ONEOK Partners

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Reconciliation of Income Tax Provision	The following table sets forth our provision for income taxes for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Current income tax provision Federal $ — $ — $ 59 State 1,830 (621 ) 1,777 Total current income tax provision 1,830 (621 ) 1,836 Deferred income tax provision Federal 8,705 5,413 5,033 State 3,365 (648 ) 5,799 Total deferred income tax provision 12,070 4,765 10,832 Total provision for income taxes $ 13,900 $ 4,144 $ 12,668
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The following table is a reconciliation of our income tax provision for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Income before income taxes $ 1,086,164 $ 602,016 $ 924,003 Less: Net income attributable to noncontrolling interests 5,497 8,330 1,037 Income attributable to ONEOK Partners, L.P. before income taxes 1,080,667 593,686 922,966 Federal statutory income tax rate 35.0 % 35.0 % 35.0 % Provision for federal income taxes 378,233 207,790 323,038 Partnership earnings not subject to tax (370,059 ) (202,143 ) (318,021 ) State income taxes, net of federal benefit 5,067 (2,078 ) 7,576 State deferred tax rate change, net of valuation allowance 128 810 — Other, net 531 (235 ) 75 Income tax provision $ 13,900 $ 4,144 $ 12,668
Schedule of Deferred Tax Assets and Liabilities	The following table sets forth the tax effects of temporary differences that gave rise to significant portions of the deferred tax assets and liabilities for the periods indicated: Years Ended December 31, 2016 2015 ( Thousands of dollars ) Deferred tax assets Federal and state net operating loss $ 8,293 $ 4,224 Other 4 7 Total deferred tax assets 8,297 4,231 Deferred tax liabilities Excess of tax over book depreciation 83,731 67,265 Regulatory assets 33 49 Total deferred tax liabilities 83,764 67,314 Net deferred tax liabilities $ 75,467 $ 63,083

UNCONSOLIDATED AFFILIATES (Tabl

UNCONSOLIDATED AFFILIATES (Tables)	12 Months Ended
	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Schedule of Equity Method Investments	Investments in Unconsolidated Affiliates - The following table sets forth our investments in unconsolidated affiliates for the periods indicated: Net Ownership Interest December 31, December 31, ( Thousands of dollars ) Northern Border Pipeline 50% $ 328,456 $ 363,231 Overland Pass Pipeline Company 50% 444,138 459,354 Other Various 186,213 125,636 Investments in unconsolidated affiliates (a) $ 958,807 $ 948,221 (a) - Equity-method goodwill (Note A ) was $40.1 million at December 31, 2016 and 2015 , respectively.
Summarized Financial Information Of Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Schedule of Equity Method Investments	Unconsolidated Affiliates Financial Information - The following tables set forth summarized combined financial information of our unconsolidated affiliates for the periods indicated: December 31, December 31, ( Thousands of dollars ) Balance Sheet Current assets $ 143,317 $ 149,439 Property, plant and equipment, net $ 2,579,607 $ 2,556,559 Other noncurrent assets $ 20,784 $ 23,722 Current liabilities $ 77,388 $ 211,037 Long-term debt $ 649,539 $ 425,521 Other noncurrent liabilities $ 69,265 $ 69,356 Accumulated other comprehensive loss $ (7,450 ) $ (5,669 ) Owners’ equity $ 1,954,966 $ 2,029,475 Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Income Statement Operating revenues $ 578,542 $ 524,496 $ 548,491 Operating expenses (a) $ 260,753 $ 304,930 $ 309,990 Net income (a) $ 293,921 $ 200,064 $ 214,410 Distributions paid to us $ 196,717 $ 155,918 $ 139,019 (a) Includes long-lived asset impairment charges in 2015 and 2014.
Equity In Net Earnings From Investments [Member]
Schedule of Equity Method Investments [Line Items]
Schedule of Equity Method Investments	Equity in Net Earnings from Investments and Impairments - The following table sets forth our equity in net earnings from investments for the periods indicated: Years Ended December 31, 2016 2015 2014 ( Thousands of dollars ) Northern Border Pipeline $ 69,990 $ 66,941 $ 69,819 Overland Pass Pipeline Company 53,984 37,783 25,906 Other 15,716 20,576 21,690 Equity in net earnings from investments $ 139,690 $ 125,300 $ 117,415 Impairment of equity investments $ — $ (180,583 ) $ (76,412 )

COMMITMENTS AND CONTINGENCIES44

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Future Minimum Rental Payments for Firm Transportation and Storage Contracts	The following table sets forth our firm transportation and storage contract payments for our continuing operations for the periods indicated: Firm Transportation and Storage Contracts ( Millions of dollars ) 2017 $ 51.5 2018 43.0 2019 37.5 2020 37.1 2021 23.0 Thereafter 35.0 Total $ 227.1

ACQUISITIONS ACQUISITIONS (Tabl

ACQUISITIONS ACQUISITIONS (Tables)	12 Months Ended
	Dec. 31, 2016
West Texas LPG Acquisition [Member]
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation [Table Text Block]	The final purchase price allocation and assessment of the fair value of the assets acquired as of the acquisition date were as follows: ( Thousands of dollars ) Cash $ 13,839 Accounts receivable 9,132 Other current assets 3,369 Property, plant and equipment Regulated 812,716 Nonregulated 157,643 Total property, plant and equipment 970,359 Total fair value of assets acquired 996,699 Accounts payable (8,621 ) Other liabilities (10,867 ) Total fair value of liabilities acquired (19,488 ) Less: Fair value of noncontrolling interest (162,438 ) Net assets acquired 814,773 Less: Cash received (13,839 ) Net cash paid for acquisition $ 800,934

SEGMENTS (Tables)

SEGMENTS (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Selected Financial Information by Reportable Segment	Operating Segment Information - The following tables set forth certain selected financial information for our operating segments for the periods indicated: Year Ended December 31, 2016 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,375,738 $ 7,168,983 $ 373,738 $ 8,918,459 Intersegment revenues 675,839 506,671 5,623 1,188,133 Total revenues 2,051,577 7,675,654 379,361 10,106,592 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (1,331,542 ) (6,321,377 ) (30,561 ) (7,683,480 ) Operating costs (285,599 ) (327,597 ) (115,628 ) (728,824 ) Equity in net earnings from investments 10,742 54,513 74,435 139,690 Other 1,600 (1,574 ) 5,530 5,556 Segment adjusted EBITDA $ 446,778 $ 1,079,619 $ 313,137 $ 1,839,534 Depreciation and amortization $ (178,548 ) $ (163,303 ) $ (46,718 ) $ (388,569 ) Total assets $ 5,320,666 $ 8,347,961 $ 1,946,318 $ 15,614,945 Capital expenditures $ 410,485 $ 105,861 $ 96,274 $ 612,620 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $1.2 billion , of which $992.8 million related to sales within the segment, cost of sales and fuel of $458.7 million and operating income of $467.9 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $238.7 million , cost of sales and fuel of $30.0 million and operating income of $100.8 million . Year Ended December 31, 2016 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 8,918,459 $ — $ 8,918,459 Intersegment revenues 1,188,133 (1,188,133 ) — Total revenues $ 10,106,592 $ (1,188,133 ) $ 8,918,459 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (7,683,480 ) $ 1,187,356 $ (6,496,124 ) Operating costs $ (728,824 ) $ 1,266 $ (727,558 ) Depreciation and amortization $ (388,569 ) $ — $ (388,569 ) Equity in net earnings from investments $ 139,690 $ — $ 139,690 Total assets $ 15,614,945 $ (145,598 ) $ 15,469,347 Capital expenditures $ 612,620 $ 9,102 $ 621,722 Year Ended December 31, 2015 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,187,390 $ 6,248,002 $ 325,676 $ 7,761,068 Intersegment revenues 649,726 331,697 6,771 988,194 Total revenues 1,837,116 6,579,699 332,447 8,749,262 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (1,265,617 ) (5,328,256 ) (34,481 ) (6,628,354 ) Operating costs (272,418 ) (314,505 ) (105,720 ) (692,643 ) Equity in net earnings from investments 17,863 38,696 68,741 125,300 Other 1,610 (3,342 ) 13,993 12,261 Segment adjusted EBITDA $ 318,554 $ 972,292 $ 274,980 $ 1,565,826 Depreciation and amortization $ (150,008 ) $ (158,709 ) $ (43,479 ) $ (352,196 ) Impairment of long-lived assets $ (73,681 ) $ (9,992 ) $ — $ (83,673 ) Impairment of equity investments $ (180,583 ) $ — $ — $ (180,583 ) Total assets $ 5,123,450 $ 8,017,799 $ 1,851,857 $ 14,993,106 Capital expenditures $ 887,938 $ 226,135 $ 58,215 $ 1,172,288 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $954.8 million , of which $770.1 million related to sales within the segment, cost of sales and fuel of $412.6 million and operating income of $306.9 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $266.9 million , cost of sales and fuel of $31.1 million and operating income of $103.7 million . Year Ended December 31, 2015 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 7,761,068 $ — $ 7,761,068 Intersegment revenues 988,194 (988,194 ) — Total revenues $ 8,749,262 $ (988,194 ) $ 7,761,068 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (6,628,354 ) $ 987,302 $ (5,641,052 ) Operating costs $ (692,643 ) $ 467 $ (692,176 ) Depreciation and amortization $ (352,196 ) $ — $ (352,196 ) Impairment of long-lived assets $ (83,673 ) $ — $ (83,673 ) Impairment of equity investments $ (180,583 ) $ — $ (180,583 ) Equity in net earnings from investments $ 125,300 $ — $ 125,300 Total assets $ 14,993,106 $ (65,520 ) $ 14,927,586 Capital expenditures $ 1,172,288 $ 13,835 $ 1,186,123 Year Ended December 31, 2014 Natural Gas Gathering and Processing Natural Gas Liquids (a) Natural Gas Pipelines (b) Total Segments ( Thousands of dollars ) Sales to unaffiliated customers $ 1,478,729 $ 10,329,609 $ 329,801 $ 12,138,139 Sales to affiliated customers 41,214 — 12,312 53,526 Intersegment revenues 1,447,665 215,772 8,343 1,671,780 Total revenues 2,967,608 10,545,381 350,456 13,863,445 Cost of sales and fuel (exclusive of depreciation and items shown separately below) (2,305,723 ) (9,435,296 ) (21,935 ) (11,762,954 ) Operating costs (257,658 ) (296,402 ) (111,037 ) (665,097 ) Equity in net earnings from investments 20,271 27,326 69,818 117,415 Other 672 (87 ) 6,900 7,485 Segment adjusted EBITDA $ 425,170 $ 840,922 $ 294,202 $ 1,560,294 Depreciation and amortization $ (123,847 ) $ (124,071 ) $ (43,318 ) $ (291,236 ) Impairment of equity investments $ (76,412 ) $ — $ — $ (76,412 ) Total assets $ 4,911,283 $ 8,143,575 $ 1,835,884 $ 14,890,742 Capital expenditures $ 898,896 $ 798,048 $ 42,991 $ 1,739,935 (a) - Our Natural Gas Liquids segment has regulated and nonregulated operations. Our Natural Gas Liquids segment’s regulated operations had revenues of $695.9 million , of which $598.1 million related to sales within the segment, cost of sales and fuel of $309.4 million and operating income of $196.1 million . (b) - Our Natural Gas Pipelines segment has regulated and nonregulated operations. Our Natural Gas Pipelines segment’s regulated operations had revenues of $290.0 million , cost of sales and fuel of $47.7 million and operating income of $106.5 million . Year Ended December 31, 2014 Total Segments Other and Eliminations Total ( Thousands of dollars ) Reconciliations of total segments to consolidated Sales to unaffiliated customers $ 12,138,139 $ — $ 12,138,139 Sales to affiliated customers 53,526 — 53,526 Intersegment revenues 1,671,780 (1,671,780 ) — Total revenues $ 13,863,445 $ (1,671,780 ) $ 12,191,665 Cost of sales and fuel (exclusive of depreciation and operating costs) $ (11,762,954 ) $ 1,674,406 $ (10,088,548 ) Operating costs $ (665,097 ) $ (4,560 ) $ (669,657 ) Depreciation and amortization $ (291,236 ) $ — $ (291,236 ) Impairment of equity investments $ (76,412 ) $ — $ (76,412 ) Equity in net earnings from investments $ 117,415 $ — $ 117,415 Total assets $ 14,890,742 $ (290,342 ) $ 14,600,400 Capital expenditures $ 1,739,935 $ 6,055 $ 1,745,990 Years Ended December 31, ( Unaudited ) 2016 2015 2014 Reconciliation of net income to total segment adjusted EBITDA ( Thousands of dollars ) Net income $ 1,072,264 $ 597,872 $ 911,335 Add: Interest expense, net of capitalized interest 366,789 338,911 281,908 Depreciation and amortization 388,569 352,196 291,236 Income taxes 13,900 4,144 12,668 Impairment charges — 264,256 76,412 Allowance for equity funds used during construction and other (1,988 ) 8,447 (13,265 ) Total segment adjusted EBITDA $ 1,839,534 $ 1,565,826 $ 1,560,294

QUARTERLY FINANCIAL DATA (UNA47

QUARTERLY FINANCIAL DATA (UNAUDITED) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Data [Abstract]
Quarterly Financial Data	Year Ended December 31, 2016 First Quarter Second Quarter Third Quarter Fourth Quarter ( Thousands of dollars, except per unit amounts ) Revenues $ 1,773,945 $ 2,133,594 $ 2,357,391 $ 2,653,529 Net income $ 256,286 $ 261,964 $ 275,411 $ 278,603 Net income attributable to ONEOK Partners, L.P. $ 253,517 $ 261,468 $ 274,308 $ 277,474 Limited partners’ per unit net income $ 0.52 $ 0.54 $ 0.59 $ 0.60 Year Ended December 31, 2015 First Quarter Second Quarter Third Quarter Fourth Quarter ( Thousands of dollars, except per unit amounts ) Revenues $ 1,804,759 $ 2,127,507 $ 1,898,418 $ 1,930,384 Net income $ 147,032 $ 211,610 $ 229,665 $ 9,565 Net income attributable to ONEOK Partners, L.P. $ 145,594 $ 209,770 $ 226,961 $ 7,217 Limited partners’ per unit net income (loss) $ 0.21 $ 0.44 $ 0.45 $ (0.33 ) The fourth quarter 2015 includes noncash impairment charges of $264.3 million related to long-lived assets and equity investments.

SUPPLEMENTAL CONDENSED CONSOL48

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Statements of Income	Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 6,858.5 $ — $ 6,858.5 Services — — 2,060.0 — 2,060.0 Total revenues — — 8,918.5 — 8,918.5 Cost of sales and fuel (exclusive of items shown separately below) — — 6,496.1 — 6,496.1 Operating expenses — — 1,116.2 — 1,116.2 (Gain) loss on sale of assets — — (9.9 ) — (9.9 ) Operating income — — 1,316.1 — 1,316.1 Equity in net earnings from investments 1,066.8 1,066.8 69.7 (2,063.6 ) 139.7 Other income (expense), net 373.5 373.5 (2.8 ) (747.0 ) (2.8 ) Interest expense (373.5 ) (373.5 ) (366.8 ) 747.0 (366.8 ) Income before income taxes 1,066.8 1,066.8 1,016.2 (2,063.6 ) 1,086.2 Income taxes — — (13.9 ) — (13.9 ) Net income 1,066.8 1,066.8 1,002.3 (2,063.6 ) 1,072.3 Less: Net income attributable to noncontrolling interests — — 5.5 — 5.5 Net income attributable to ONEOK Partners, L.P. $ 1,066.8 $ 1,066.8 $ 996.8 $ (2,063.6 ) $ 1,066.8 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 6,098.3 $ — $ 6,098.3 Services — — 1,662.8 — 1,662.8 Total revenues — — 7,761.1 — 7,761.1 Cost of sales and fuel (exclusive of items shown separately below) — — 5,641.1 — 5,641.1 Impairment of long-lived assets — — 83.7 — 83.7 Operating expenses — — 1,044.3 — 1,044.3 (Gain) loss on sale of assets — — (6.1 ) — (6.1 ) Operating income — — 998.1 — 998.1 Equity in net earnings from investments 589.5 589.5 58.4 (1,112.1 ) 125.3 Impairment of equity investments — — (180.6 ) — (180.6 ) Other income (expense), net 371.0 371.0 (1.9 ) (742.0 ) (1.9 ) Interest expense (371.0 ) (371.0 ) (338.9 ) 742.0 (338.9 ) Income before income taxes 589.5 589.5 535.1 (1,112.1 ) 602.0 Income taxes — — (4.1 ) — (4.1 ) Net income 589.5 589.5 531.0 (1,112.1 ) 597.9 Less: Net income attributable to noncontrolling interests — — 8.4 — 8.4 Net income attributable to ONEOK Partners, L.P. $ 589.5 $ 589.5 $ 522.6 $ (1,112.1 ) $ 589.5 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Revenues Commodity sales $ — $ — $ 10,725.0 $ — $ 10,725.0 Services — — 1,466.7 — 1,466.7 Total revenues — — 12,191.7 — 12,191.7 Cost of sales and fuel (exclusive of items shown separately below) — — 10,088.6 — 10,088.6 Operating expenses — — 960.9 — 960.9 (Gain) loss on sale of assets — — (6.6 ) — (6.6 ) Operating income — — 1,148.8 — 1,148.8 Equity in net earnings from investments 910.3 910.3 47.6 (1,750.8 ) 117.4 Impairment of equity investments — — (76.4 ) — (76.4 ) Other income (expense), net 331.7 331.7 16.1 (663.4 ) 16.1 Interest expense,net (331.7 ) (331.7 ) (281.9 ) 663.4 (281.9 ) Income before income taxes 910.3 910.3 854.2 (1,750.8 ) 924.0 Income taxes — — (12.7 ) — (12.7 ) Net income 910.3 910.3 841.5 (1,750.8 ) 911.3 Less: Net income attributable to noncontrolling interests — — 1.0 — 1.0 Net income attributable to ONEOK Partners, L.P. $ 910.3 $ 910.3 $ 840.5 $ (1,750.8 ) $ 910.3
Condensed Consolidating Statements of Comprehensive Income	Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 1,066.8 $ 1,066.8 $ 1,002.3 $ (2,063.6 ) $ 1,072.3 Other comprehensive income (loss) Unrealized gains (losses) on derivatives (35.8 ) (78.5 ) (78.5 ) 157.0 (35.8 ) Realized (gains) losses on derivatives recognized in net income (10.7 ) (26.4 ) (26.4 ) 52.8 (10.7 ) Other comprehensive income (loss) on investments in unconsolidated affiliates (1.8 ) (1.8 ) (1.8 ) 3.6 (1.8 ) Total other comprehensive income (loss) (48.3 ) (106.7 ) (106.7 ) 213.4 (48.3 ) Comprehensive income 1,018.5 960.1 895.6 (1,850.2 ) 1,024.0 Less: Comprehensive income attributable to noncontrolling interests — — 5.5 — 5.5 Comprehensive income attributable to ONEOK Partners, L.P. $ 1,018.5 $ 960.1 $ 890.1 $ (1,850.2 ) $ 1,018.5 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 589.5 $ 589.5 $ 531.0 $ (1,112.1 ) $ 597.9 Other comprehensive income (loss) Unrealized gains (losses) on derivatives 47.5 70.1 70.1 (140.2 ) 47.5 Realized (gains) losses on derivatives recognized in net income (67.0 ) (81.1 ) (81.1 ) 162.2 (67.0 ) Other comprehensive income (loss) on investments in unconsolidated affiliates (1.9 ) (1.9 ) (1.9 ) 3.8 (1.9 ) Total other comprehensive income (loss) (21.4 ) (12.9 ) (12.9 ) 25.8 (21.4 ) Comprehensive income 568.1 576.6 518.1 (1,086.3 ) 576.5 Less: Comprehensive income attributable to noncontrolling interests — — 8.4 — 8.4 Comprehensive income attributable to ONEOK Partners, L.P. $ 568.1 $ 576.6 $ 509.7 $ (1,086.3 ) $ 568.1 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Net income $ 910.3 $ 910.3 $ 841.5 $ (1,750.8 ) $ 911.3 Other comprehensive income (loss) Unrealized gains (losses) on derivatives (64.6 ) 32.4 32.4 (64.8 ) (64.6 ) Realized (gains) losses on derivatives recognized in net income 31.6 21.1 21.1 (42.2 ) 31.6 Total other comprehensive income (loss) (33.0 ) 53.5 53.5 (107.0 ) (33.0 ) Comprehensive income 877.3 963.8 895.0 (1,857.8 ) 878.3 Less: Comprehensive income attributable to noncontrolling interests — — 1.0 — 1.0 Comprehensive income attributable to ONEOK Partners, L.P. $ 877.3 $ 963.8 $ 894.0 $ (1,857.8 ) $ 877.3
Condensed Consolidating Balance Sheets	December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total Assets ( Millions of dollars ) Current assets Cash and cash equivalents $ — $ 0.4 $ — $ — $ 0.4 Accounts receivable, net — — 872.3 — 872.3 Affiliate receivables — — 1.0 — 1.0 Natural gas and natural gas liquids in storage — — 140.0 — 140.0 Materials and supplies — — 60.9 — 60.9 Other current assets — — 99.6 — 99.6 Total current assets — 0.4 1,173.8 — 1,174.2 Property, plant and equipment Property, plant and equipment — — 14,854.7 — 14,854.7 Accumulated depreciation and amortization — — 2,392.0 — 2,392.0 Net property, plant and equipment — — 12,462.7 — 12,462.7 Investments and other assets Intercompany notes receivable 10,615.0 7,031.3 — (17,646.3 ) — Other assets 3,269.6 6,805.4 1,457.2 (9,699.8 ) 1,832.4 Total investments and other assets 13,884.6 13,836.7 1,457.2 (27,346.1 ) 1,832.4 Total assets $ 13,884.6 $ 13,837.1 $ 15,093.7 $ (27,346.1 ) $ 15,469.3 Liabilities and equity Current liabilities Current maturities of long-term debt $ 400.0 $ — $ 7.7 $ — $ 407.7 Short-term borrowings 1,110.3 — — — 1,110.3 Accounts payable — — 862.4 — 862.4 Affiliate payables — — 68.2 — 68.2 Other current liabilities 99.9 — 275.9 — 375.8 Total current liabilities 1,610.2 — 1,214.2 — 2,824.4 Intercompany debt — 10,615.0 7,031.3 (17,646.3 ) — Long-term debt, excluding current maturities 6,254.7 — 36.6 — 6,291.3 Deferred credits and other liabilities — — 175.8 — 175.8 Commitments and contingencies Equity Equity excluding noncontrolling interests in consolidated subsidiaries 6,019.7 3,222.1 6,477.7 (9,699.8 ) 6,019.7 Noncontrolling interests in consolidated subsidiaries — — 158.1 — 158.1 Total equity 6,019.7 3,222.1 6,635.8 (9,699.8 ) 6,177.8 Total liabilities and equity $ 13,884.6 $ 13,837.1 $ 15,093.7 $ (27,346.1 ) $ 15,469.3 December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total Assets ( Millions of dollars ) Current assets Cash and cash equivalents $ — $ 5.1 $ — $ — $ 5.1 Accounts receivable, net — — 593.4 — 593.4 Affiliate receivables — — 8.0 — 8.0 Natural gas and natural gas liquids in storage — — 128.1 — 128.1 Materials and supplies — — 76.7 — 76.7 Other current assets 4.1 — 67.8 — 71.9 Total current assets 4.1 5.1 874.0 — 883.2 Property, plant and equipment Property, plant and equipment — — 14,307.5 — 14,307.5 Accumulated depreciation and amortization — — 2,050.7 — 2,050.7 Net property, plant and equipment — — 12,256.8 — 12,256.8 Investments and other assets Intercompany notes receivable 10,144.9 7,781.8 — (17,926.7 ) — Other assets 3,594.0 5,952.0 1,425.2 (9,183.6 ) 1,787.6 Total investments and other assets 13,738.9 13,733.8 1,425.2 (27,110.3 ) 1,787.6 Total assets $ 13,743.0 $ 13,738.9 $ 14,556.0 $ (27,110.3 ) $ 14,927.6 Liabilities and equity Current liabilities Current maturities of long-term debt $ 100.0 $ — $ 7.7 $ — $ 107.7 Short-term borrowings 546.3 — — — 546.3 Accounts payable — — 605.4 — 605.4 Affiliate payables — — 27.1 — 27.1 Other current liabilities 112.5 — 181.4 — 293.9 Total current liabilities 758.8 — 821.6 — 1,580.4 Intercompany debt — 10,144.9 7,781.8 (17,926.7 ) — Long-term debt, excluding current maturities 6,651.0 — 44.3 — 6,695.3 Deferred credits and other liabilities — — 154.6 — 154.6 Commitments and contingencies Equity Equity excluding noncontrolling interests in consolidated subsidiaries 6,333.2 3,594.0 5,589.6 (9,183.6 ) 6,333.2 Noncontrolling interests in consolidated subsidiaries — — 164.1 — 164.1 Total equity 6,333.2 3,594.0 5,753.7 (9,183.6 ) 6,497.3 Total liabilities and equity $ 13,743.0 $ 13,738.9 $ 14,556.0 $ (27,110.3 ) $ 14,927.6
Condensed Consolidating Statements of Cash Flows	Year Ended December 31, 2016 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,334.5 $ 70.0 $ 1,414.3 $ (1,332.0 ) $ 1,486.8 Investing activities Capital expenditures — — (621.7 ) — (621.7 ) Other investing activities — 34.9 (25.8 ) — 9.1 Cash provided by (used in) investing activities — 34.9 (647.5 ) — (612.6 ) Financing activities Cash distributions: General and limited partners (1,332.0 ) (1,332.0 ) — 1,332.0 (1,332.0 ) Noncontrolling interests — — (7.5 ) — (7.5 ) Intercompany borrowings (advances), net (470.8 ) 1,222.4 (751.6 ) — — Borrowing (repayment) of short-term borrowings, net 563.9 — — — 563.9 Issuance of long-term debt, net of discounts 1,000.0 — — — 1,000.0 Debt financing costs (2.8 ) — — — (2.8 ) Repayment of long-term debt (1,100.0 ) — (7.7 ) — (1,107.7 ) Other 7.2 — — — 7.2 Cash provided by (used in) financing activities (1,334.5 ) (109.6 ) (766.8 ) 1,332.0 (878.9 ) Change in cash and cash equivalents — (4.7 ) — — (4.7 ) Cash and cash equivalents at beginning of period — 5.1 — — 5.1 Cash and cash equivalents at end of period $ — $ 0.4 $ — $ — $ 0.4 Year Ended December 31, 2015 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,196.7 $ 66.9 $ 1,038.9 $ (1,230.5 ) $ 1,072.0 Investing activities Capital expenditures — — (1,186.1 ) — (1,186.1 ) Other investing activities — 24.1 (26.5 ) — (2.4 ) Cash provided by (used in) investing activities — 24.1 (1,212.6 ) — (1,188.5 ) Financing activities Cash distributions: General and limited partners (1,230.5 ) (1,230.5 ) — 1,230.5 (1,230.5 ) Noncontrolling interests — — (11.7 ) — (11.7 ) Intercompany borrowings (advances), net (1,295.1 ) 1,102.1 193.0 — — Borrowing (repayment) of short-term borrowings, net (509.0 ) — — — (509.0 ) Issuance of long-term debt, net of discounts 798.9 — — — 798.9 Debt financing costs (7.7 ) — — — (7.7 ) Repayment of long-term debt — — (7.6 ) — (7.6 ) Issuance of common units, net of issuance costs 1,025.7 — — — 1,025.7 Contribution from general partner 21.0 — — — 21.0 Cash provided by (used in) financing activities (1,196.7 ) (128.4 ) 173.7 1,230.5 79.1 Change in cash and cash equivalents — (37.4 ) — — (37.4 ) Cash and cash equivalents at beginning of period — 42.5 — — 42.5 Cash and cash equivalents at end of period $ — $ 5.1 $ — $ — $ 5.1 Year Ended December 31, 2014 Parent Guarantor Subsidiary Combined Non-Guarantor Subsidiaries Consolidating Entries Total ( Millions of dollars ) Operating activities Cash provided by operating activities $ 1,155.7 $ 69.8 $ 1,136.5 $ (1,052.2 ) $ 1,309.8 Investing activities Capital expenditures — — (1,746.0 ) — (1,746.0 ) Other investing activities — 17.7 (804.7 ) — (787.0 ) Cash provided by (used in) investing activities — 17.7 (2,550.7 ) — (2,533.0 ) Financing activities Cash distributions: General and limited partners (1,052.2 ) (1,052.2 ) — 1,052.2 (1,052.2 ) Noncontrolling interests — — (0.6 ) — (0.6 ) Intercompany borrowings (advances), net (2,295.2 ) 872.7 1,422.5 — — Borrowing (repayment) of short-term borrowings, net 1,055.3 — — — 1,055.3 Repayment of long-term debt — — (7.7 ) — (7.7 ) Issuance of common units, net of issuance costs 1,113.1 — — — 1,113.1 Contribution from general partner 23.3 — — — 23.3 Cash provided by (used in) financing activities (1,155.7 ) (179.5 ) 1,414.2 1,052.2 1,131.2 Change in cash and cash equivalents — (92.0 ) — — (92.0 ) Cash and cash equivalents at beginning of period — 134.5 — — 134.5 Cash and cash equivalents at end of period $ — $ 42.5 $ — $ — $ 42.5

SUMMARY OF SIGNIFICANT ACCOUN49

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Entity [Line Items]
General partnership ownership interest (in hundredths)	41.20%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	98.00%
Regulatory Assets	$ 5.5	$ 5.8
Maximum Time Period Regulatory Assets Are Being Recovered (In Years)	50 years
General Partner [Member]
Entity [Line Items]
General partnership ownership interest (in hundredths)	2.00%

ONEOK PARTNERS ACQUISITION (Det

ONEOK PARTNERS ACQUISITION (Details) - Subsequent Event [Member]	3 Months Ended
	Mar. 31, 2017
Subsequent Event [Line Items]
Subsequent Event, Date	Jan. 31, 2017
Subsequent Event, Description	We and ONEOK entered into the Merger Agreement in which ONEOK will acquire all of our outstanding common units representing limited partner interests in us not already directly or indirectly owned by ONEOK in an all stock-for-unit transaction at a ratio of 0.985 of ONEOK common shares per common unit of ONEOK Partners, in a taxable transaction to our common unitholders. Following completion of the Merger Transaction, all of our outstanding common units will be owned by ONEOK and will no longer be publicly traded. All of our outstanding debt is expected to remain outstanding. We and ONEOK expect to enter into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees and becomes liable for the indebtedness of each other party to the agreement.

FAIR VALUE MEASUREMENTS - Part

FAIR VALUE MEASUREMENTS - Part 1 (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
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	$ 34,400
Cash posted - total	67,700
Long-term Debt, Fair Value	7,100,000	6,200,000
Long-term Debt	6,700,000	6,800,000
Cash posted - offsetting derivative net liability positions under master-netting arrangements	51,600	0
Cash posted - remaining in excess of derivative net liability positions included in consolidated Balance Sheets	16,100
Fair Value, Measurements, Recurring [Member]
Derivative assets
Commodity contracts - financial	951	3,760
Commodity contracts - physical		3,591
Interest-rate contracts	47,457
Total derivative assets	48,408	7,351
Derivative assets netting	(4,760)	(42,414)
Derivative Liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical	(3,022)
Interest-rate contracts	(12,795)	(9,936)
Total derivative liabilities	15,817	9,936
Derivative liabilities netting	56,319	8,026
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member]
Derivative assets
Commodity contracts - financial	5,711	46,174
Commodity contracts - physical		3,591
Interest-rate contracts	47,457
Total derivative assets	53,168	49,765
Derivative Liabilities
Commodity contracts - financial	(56,319)	(8,026)
Commodity contracts - physical	(3,022)
Interest-rate contracts	(12,795)	(9,936)
Total derivative liabilities	72,136	17,962
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets
Commodity contracts - financial	1,147	38,921
Commodity contracts - physical		0
Interest-rate contracts	0
Total derivative assets	1,147	38,921
Derivative Liabilities
Commodity contracts - financial	(31,458)	(4,513)
Commodity contracts - physical	0
Interest-rate contracts	0	0
Total derivative liabilities	31,458	4,513
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets
Commodity contracts - financial	0	0
Commodity contracts - physical		0
Interest-rate contracts	47,457
Total derivative assets	47,457	0
Derivative Liabilities
Commodity contracts - financial	0	0
Commodity contracts - physical	0
Interest-rate contracts	(12,795)	(9,936)
Total derivative liabilities	12,795	9,936
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets
Commodity contracts - financial	4,564	7,253
Commodity contracts - physical		3,591
Interest-rate contracts	0
Total derivative assets	4,564	10,844
Derivative Liabilities
Commodity contracts - financial	(24,861)	(3,513)
Commodity contracts - physical	(3,022)
Interest-rate contracts	0	0
Total derivative liabilities	$ 27,883	$ 3,513

FAIR VALUE MEASUREMENTS - Par52

FAIR VALUE MEASUREMENTS - Part 2 (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets And Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract]
Net assets (liabilities) at beginning of period	$ 7,331	$ 9,285
Total realized/unrealized gains (losses): [Abstract]
Included in earnings	(320)	216
Included in other comprehensive income (loss)	(30,330)	(2,170)
Net assets (liabilities) at end of period	(23,319)	7,331
Transfers between levels	$ 0	$ 0

RISK MANAGEMENT AND HEDGING A53

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES - Part 1 (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Assets	$ 53,168,000	$ 49,765,000
(Liabilities)	(72,136,000)	(17,962,000)
Derivative, Net Liability Position, Aggregate Fair Value	0
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	48,822,000	42,846,000
(Liabilities)	(67,897,000)	(11,376,000)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	4,346,000	6,919,000
(Liabilities)	(4,239,000)	(6,586,000)
Natural Gas Pipelines [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net	0	0
Other Current Assets [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	1,155,000	39,255,000
Other Current Assets [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Physical Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	0	3,591,000
Other Current Assets [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	4,346,000	6,919,000
Other Current Liabilities [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
(Liabilities)	(49,938,000)	(1,440,000)
Other Current Liabilities [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Physical Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
(Liabilities)	(3,022,000)	0
Other Current Liabilities [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
(Liabilities)	(4,239,000)	(6,586,000)
Other Current Liabilities [Member] | Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
(Liabilities)	(12,795,000)	(9,936,000)
Other Assets [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	210,000	0
Other Assets [Member] | Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Assets	47,457,000	0
Other Liabilities [Member] | Commodity Contract [Member] | Designated as Hedging Instrument [Member] | Financial Derivative Instrument [Member]
Derivatives, Fair Value [Line Items]
(Liabilities)	$ (2,142,000)	$ 0

RISK MANAGEMENT AND HEDGING A54

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES - Part 2 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MMcfMMBbls	Dec. 31, 2015USD ($)MMcfMMBbls
Derivative [Line Items]
Notional Amount Of Cash Flow Hedge Instruments Settled | $		$ 500
Not Designated as Hedging Instrument [Member] | Futures, forwards and swaps [Member] | Crude Oil and NGL [Member] | Fixed Price [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount | MMBbls	0.5	0.6
Not Designated as Hedging Instrument [Member] | Futures, forwards and swaps [Member] | Crude Oil and NGL [Member] | Fixed Price [Member] | Sold [Member]
Derivative [Line Items]
Notional amount | MMBbls	(0.7)	(0.6)
Not Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Fixed Price [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount	400	0
Not Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Fixed Price [Member] | Sold [Member]
Derivative [Line Items]
Notional amount	0	0
Not Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Basis [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount	400	0
Not Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Basis [Member] | Sold [Member]
Derivative [Line Items]
Notional amount	0	0
Designated as Hedging Instrument [Member] | Futures, forwards and swaps [Member] | Crude Oil and NGL [Member] | Fixed Price [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount | MMBbls	0	0
Designated as Hedging Instrument [Member] | Futures, forwards and swaps [Member] | Crude Oil and NGL [Member] | Fixed Price [Member] | Sold [Member]
Derivative [Line Items]
Notional amount | MMBbls	(3.6)	(2.3)
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Purchased [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 2,150	$ 400
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Sold [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 0	$ 0
Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Fixed Price [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount	0	0
Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Fixed Price [Member] | Sold [Member]
Derivative [Line Items]
Notional amount	(38,400)	(27,100)
Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Basis [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount	0	0
Designated as Hedging Instrument [Member] | Futures and swaps [Member] | Natural Gas [Member] | Basis [Member] | Sold [Member]
Derivative [Line Items]
Notional amount	(38,400)	(27,100)
Designated as Hedging Instrument [Member] | Options [Member] | Natural Gas [Member] | Fixed Price [Member] | Purchased [Member]
Derivative [Line Items]
Notional amount	49,500	0
Designated as Hedging Instrument [Member] | Options [Member] | Natural Gas [Member] | Fixed Price [Member] | Sold [Member]
Derivative [Line Items]
Notional amount	0	0
LIBOR Based Interest Payments [Member] | Forward Contracts [Member] | Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	$ 1,000
Forecasted Debt Issuances [Member] | Forward Contracts [Member] | Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Notional Amount | $	1,200	$ 400
Derivative, Notional Amount, New Contracts | $	$ 750

RISK MANAGEMENT AND HEDGING A55

RISK MANAGEMENT AND HEDGING ACTIVITIES USING DERIVATIVES - Part 3 (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Realized Loss On Settled Interest Rate Swaps Recorded in AOCI		$ 55,100
Accumulated other comprehensive loss	$ (161,526)	(113,282)	$ (91,823)
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(35,752)	47,500	(64,639)
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income (effective portion)	10,717	67,034	(31,653)
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) On Cash Flow Hedges Net Of Tax Accumulated Other Comprehensive Income Loss	(63,400)
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	(61,500)
Commodity Cash Flow Hedge Gain (Loss) To Be Reclassified After Next 12 Months Net	(1,900)
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	(78,513)	70,065	32,354
Commodity Contract [Member] | Sales [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income (effective portion)	26,422	81,089	(21,052)
Interest Rate Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	(16,600)
Amount of accumulated other comprehensive income (loss) attributable primarily to settled interest-rate swaps.	(125,900)
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	42,761	(22,565)	(96,993)
Interest Rate Contract [Member] | Interest Expense [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gain (loss) reclassified from accumulated other comprehensive income (loss) into net income (effective portion)	$ (15,705)	$ (14,055)	$ (10,601)

PROPERTY, PLANT AND EQUIPMENT -

PROPERTY, PLANT AND EQUIPMENT - (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 14,854,696	$ 14,307,546
Accumulated depreciation and amortization	(2,392,004)	(2,050,755)
Property, Plant and Equipment, Net	12,462,692	12,256,791
Construction in Progress Expenditures Incurred but Not yet Paid	83,000	115,700	$ 187,200
Impairment of long-lived assets	0	83,673	$ 0
Non-Regulated Property, Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	(1,526,400)	(1,290,931)
Non-Regulated Property, Plant and Equipment [Member] | Gathering pipelines and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	3,352,963	2,961,388
Non-Regulated Property, Plant and Equipment [Member] | Processing and fractionation and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	3,831,966	3,627,062
Non-Regulated Property, Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	558,695	510,820
Non-Regulated Property, Plant and Equipment [Member] | Transmission pipelines and related equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	689,804	598,375
Non-Regulated Property, Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	264,049	226,858
Non-Regulated Property, Plant and Equipment [Member] | Construction Work in Process [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	371,337	690,179
Regulated Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	(865,604)	(759,824)
Regulated Property Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	13,524	22,085
Regulated Property Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	54,643	53,962
Regulated Property Plant and Equipment [Member] | Construction Work in Process [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	62,634	83,461
Regulated Property Plant and Equipment [Member] | Natural Gas Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,345,740	1,325,235
Regulated Property Plant and Equipment [Member] | Natural Gas Liquids Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 4,309,341	4,208,121
Minimum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Gathering pipelines and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Minimum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Processing and fractionation and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Minimum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Minimum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Transmission pipelines and related equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Minimum [Member] | Non-Regulated Property, Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	2 years
Minimum [Member] | Regulated Property Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Minimum [Member] | Regulated Property Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	2 years
Minimum [Member] | Regulated Property Plant and Equipment [Member] | Natural Gas Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Minimum [Member] | Regulated Property Plant and Equipment [Member] | Natural Gas Liquids Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Maximum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Gathering pipelines and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	40 years
Maximum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Processing and fractionation and related equipment [member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	40 years
Maximum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	54 years
Maximum [Member] | Non-Regulated Property, Plant and Equipment [Member] | Transmission pipelines and related equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	54 years
Maximum [Member] | Non-Regulated Property, Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	60 years
Maximum [Member] | Regulated Property Plant and Equipment [Member] | Storage and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	25 years
Maximum [Member] | Regulated Property Plant and Equipment [Member] | General plant and other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Maximum [Member] | Regulated Property Plant and Equipment [Member] | Natural Gas Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	77 years
Maximum [Member] | Regulated Property Plant and Equipment [Member] | Natural Gas Liquids Transmission Pipelines and Related Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	88 years
Natural Gas Gathering And Processing [Member]
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets		$ 63,500
Natural Gas Liquids [Member] | Regulated Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Average Depreciation Rate	1.90%	1.90%	2.00%
Natural Gas Pipelines [Member] | Regulated Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Average Depreciation Rate	2.10%	2.10%	2.10%
Natural Gas Gathering And Processing and Natural Gas Liquids [Member]
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets		$ 20,200

GOODWILL AND INTANGIBLE ASSET57

GOODWILL AND INTANGIBLE ASSETS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Goodwill	$ 488,718	$ 488,718
Amortization expense for intangible assets	11,900	11,900	$ 11,800
Future amortization expense for next five years [Abstract]
Future amortization expense, year one	11,900
Future amortization expense, year two	11,900
Future amortization expense, year three	11,900
Future amortization expense, year four	11,900
Future amortization expense, year five	11,900
Gross intangible assets and accumulated amortization [Abstract]
Gross intangible assets	426,068	426,068
Accumulated amortization	(101,809)	(89,909)
Net intangible assets	324,259	336,159
Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Goodwill	112,141	112,141
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Goodwill	129,011	129,011
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Goodwill	$ 247,566	$ 247,566
Minimum [Member] | Natural Gas Gathering And Processing and Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Finite-Lived Intangible Asset, Useful Life	20 years
Maximum [Member] | Natural Gas Gathering And Processing and Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Finite-Lived Intangible Asset, Useful Life	40 years

DEBT (Details)

DEBT (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)Rate	Dec. 31, 2015USD ($)Rate
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 7,854,534	$ 7,398,247
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	45,300	48,945
Current maturities	(407,650)	(107,650)
Short-term Debt	(1,110,277)	(546,340)
Long-term debt	6,291,307	6,695,312
Long-term Debt, by Maturity [Abstract]
2,017	407,700
2,018	432,700
2,019	1,507,700
2,020	307,700
2,021	7,700
Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial Paper	$ 1,110,277	$ 246,340
Short-term Debt, Weighted Average Interest Rate | Rate	1.27%	1.23%
Maximum Amount Of Commercial Paper	$ 2,400,000
Partnership Credit Agreement [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	0	$ 300,000
Short-term Debt, Weighted Average Interest Rate | Rate		1.60%
Letters of Credit Outstanding, Amount	14,000	$ 14,000
Line of credit facility sublimit	100,000
Line of Credit Facility Swingline Subfacility	150,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,300,000
Line of Credit Facility, Interest Rate Description	borrowings, if any, will accrue interest at LIBOR plus 117.5 basis points
Line Of Credit Facility, Annual Facility Fee Description	the annual facility fee is 20 basis points.
Indebtedness To Adjusted Ebitda Maximum	5
Aggregate Purchase Price For Acquisitions Threshold Which Adjusts Allowable Ratio Of Indebtedness To Adjusted Ebitda	$ 25,000
Indebtedness To Adjusted Ebitda From Acquisitions Maximum	5.5
Indebtedness To Adjusted Ebitda Current	4.1
ONEOK Partners [Member]
Debt Instrument [Line Items]
Debt instrument covenant description	Our senior notes are governed by an indenture, dated as of September 25, 2006, between us and Wells Fargo Bank, N.A., the trustee, as supplemented. The indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series. The indenture contains covenants including, among other provisions, limitations on our ability to place liens on our property or assets and to sell and lease back our property. The indenture includes an event of default upon acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of any of our outstanding senior notes to declare those notes immediately due and payable in full
Debt instrument call feature	We may redeem our senior notes due 2019, 2036 and 2037, in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date. We may redeem our senior notes due 2017 and our senior notes due 2022 at par starting one month and three months, respectively, before their maturity dates. We may redeem our senior notes due 2041 at a redemption price equal to the principal amount, plus accrued and unpaid interest, starting six months before its maturity date. Prior to that date, we may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. We may redeem our senior notes due 2018, 2020, 2023, 2025, and 2043 at par, plus accrued and unpaid interest to the redemption date, starting one month, one month, three months, three months, and six months, respectively, before their maturity dates. Prior to these dates, we may redeem these notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective note plus accrued and unpaid interest to the redemption date.
Long-term Debt, by Maturity [Abstract]
2,017	$ 400,000
2,018	425,000
2,019	1,500,000
2,020	300,000
2,021	0
ONEOK Partners [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Proceeds from Debt, Net of Issuance Costs		792,300
Senior Notes, Noncurrent		800,000
ONEOK Partners [Member] | Note Payable from Public Offering Due 2016 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 0	650,000
Interest rates (in hundredths) | Rate	3.25%
ONEOK Partners [Member] | Notes Payable due 2016 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 0	$ 450,000
Interest rates (in hundredths) | Rate	6.15%	6.15%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2017 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 400,000	$ 400,000
Interest rates (in hundredths) | Rate	2.00%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2018 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 425,000	425,000
Interest rates (in hundredths) | Rate	3.20%
ONEOK Partners [Member] | Term Loan Agreement [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,000,000	0
Delayed-Draw Unsecured Senior Term Loan	1,000,000
Proceeds from Debt, Net of Issuance Costs	$ 1,000,000
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate | Rate	2.04%
ONEOK Partners [Member] | Notes Payables due 2019 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 500,000	500,000
Interest rates (in hundredths) | Rate	8.625%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2020 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 300,000	$ 300,000
Interest rates (in hundredths) | Rate	3.80%	3.80%
ONEOK Partners [Member] | Note Payable 2 from Public Offering Due 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 900,000	$ 900,000
Interest rates (in hundredths) | Rate	3.375%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2023 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 425,000	425,000
Interest rates (in hundredths) | Rate	5.00%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2025 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 500,000	$ 500,000
Interest rates (in hundredths) | Rate	4.90%	4.90%
ONEOK Partners [Member] | Notes Payables due 2036 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 600,000	$ 600,000
Interest rates (in hundredths) | Rate	6.65%
ONEOK Partners [Member] | Notes Payables due 2037 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 600,000	600,000
Interest rates (in hundredths) | Rate	6.85%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2041 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 650,000	650,000
Interest rates (in hundredths) | Rate	6.125%
ONEOK Partners [Member] | Note Payable from Public Offering Due 2043 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 400,000	400,000
Interest rates (in hundredths) | Rate	6.20%
Guardian Pipeline [Member]
Debt Instrument [Line Items]
Debt instrument covenant description	Guardian Pipeline’s senior notes contain financial covenants that require the maintenance of certain financial ratios as defined in the master shelf agreement based on Guardian Pipeline’s financial position and results of operations. Upon any breach of these covenants, all amounts outstanding under the master shelf agreement may become due and payable immediately
Debt Instrument, Covenant Compliance	At December 31, 2016, Guardian Pipeline was in compliance with its financial covenants
Guardian Pipeline [Member] | Notes Payables due 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 44,257	$ 51,907
Average interest rate (in hundredths) | Rate	7.88%
Long-term Debt, by Maturity [Abstract]
2,017	$ 7,700
2,018	7,700
2,019	7,700
2,020	7,700
2,021	$ 7,700

EQUITY (Details)

EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	3 Months Ended													12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Equity [Abstract]
Partnership Agreement														Partnership Agreement - Available cash, as defined in our Partnership Agreement generally will be distributed to our general partner and limited partners according to their partnership percentages of 2 percent and 98 percent, respectively.  Our general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met during the quarter.  Under the incentive distribution provisions, as set forth in our Partnership Agreement, our general partner receives: 15 percent of amounts distributed in excess of $0.3025 per unit; 25 percent of amounts distributed in excess of $0.3575 per unit; and 50 percent of amounts distributed in excess of $0.4675 per unit.
Partnership Capital Distributions [Line Items]
General partnership ownership interest (in hundredths)														41.20%
Rights to receive increased quarterly distribution on Class B Units														Our Class B limited partner units are entitled to receive increased quarterly distributions equal to 110 percent of the distributions paid with respect to our common units.
Number of common units owned by related party	41.3													41.3
Aggregate dollar amount of common units available for issuance and sale under the Equity Distribution Agreement.														$ 650,000
Remaining capacity of at the market equity program	$ 138,000													138,000
Contribution from general partner															$ 20,990	$ 23,155
Total distributions														$ 1,339,503	$ 1,242,165	$ 1,052,794
Percentage of increase in quarterly distributions entitled to Class B limited partners units														123.50%
Percentage of increase in quarterly distribution payable on Class B limited partner units upon removal of general partner														123.50%
General Partner [Member]
Partnership Capital Distributions [Line Items]
General partnership ownership interest (in hundredths)														2.00%
Distributions Paid [Member]
Partnership Capital Distributions [Line Items]
Distributions Per Limited Partnership and General Partnership Unit, Outstanding, Basic														$ 3.16	$ 3.16	$ 3.01
Total distributions														$ 1,332,003	$ 1,230,475	$ 1,052,245
Distributions Paid [Member] | General Partner [Member]
Partnership Capital Distributions [Line Items]
General partner distributions														26,640	24,610	21,044
Incentive distribution														402,152	371,500	304,999
Distributions to general partner														428,792	396,110	326,043
Distributions Paid [Member] | Limited Partner [Member]
Partnership Capital Distributions [Line Items]
Limited partner distributions to ONEOK														361,292	310,230	279,292
Partners Capital Account Distributions to Other Unitholders														$ 541,919	$ 524,135	$ 446,910
Distributions Declared [Member]
Partnership Capital Distributions [Line Items]
Distributions Per Limited Partnership and General Partnership Unit, Outstanding, Basic	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.790	$ 0.775	$ 0.760	$ 0.745	$ 0.730	$ 3.16	$ 3.16	$ 3.07
Total distributions														$ 1,332,003	$ 1,267,770	$ 1,105,457
Distributions Declared [Member] | General Partner [Member]
Partnership Capital Distributions [Line Items]
General partner distributions														26,640	25,356	22,109
Incentive distribution														402,152	382,759	326,022
Distributions to general partner														428,792	408,115	348,131
Distributions Declared [Member] | Limited Partner [Member]
Partnership Capital Distributions [Line Items]
Limited partner distributions to ONEOK														361,292	327,250	284,860
Partners Capital Account Distributions to Other Unitholders														$ 541,919	$ 532,405	$ 472,466
Issued under public offering [Member]
Partnership Capital Distributions [Line Items]
Partners' Capital Account, Units, Sold in Public Offering											13.9
Public offering price of common units											$ 52.94
Proceeds from Sale of Interest in Partnership Unit											$ 714,500
Contribution from general partner											$ 15,000
Private Placement [Member]
Partnership Capital Distributions [Line Items]
Partners Capital Account Units Sold Under Equity Distribution Agreement						3.3
Number of common units to related party in a private placement (in number of units)						21.5
Per Unit Offering Price Under Private Placement						$ 30.17
Proceeds from Sale of Interest in Partnership Unit						$ 749,000
Contribution from general partner						$ 15,300
Issued Under Equity Distribution Agreement [Member]
Partnership Capital Distributions [Line Items]
Partners Capital Account Units Sold Under Equity Distribution Agreement														0	10.5	7.9
Proceeds from Sale of Interest in Partnership Unit															$ 381,600	$ 402,100
West Texas LPG Pipeline Limited Partnership [Member]
Partnership Capital Distributions [Line Items]
Business Acquisition, Description of Acquired Entity																80 percent interest
West Texas LPG and Mesquite Systems [Member]
Partnership Capital Distributions [Line Items]
Acquisition date																Nov. 30, 2014

RELATED-PARTY TRANSACTIONS (Det

RELATED-PARTY TRANSACTIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transactions [Abstract]
General partnership ownership interest (in hundredths)	41.20%
Related Party Transaction [Line Items]
Contribution from general partner		$ 20,990	$ 23,155
Roadrunner Gas Transmission [Member]
Expenses [Abstract]
Related Party Transaction, Amounts of Transaction	$ 7,700	5,400
ONEOK [Member]
Transactions With Related Parties [Abstract]
Revenues	0	0	53,526
Expenses [Abstract]
Cost of sales and fuel	0	0	10,835
Operating expenses	388,142	368,346	330,541
Total expenses	$ 388,142	$ 368,346	$ 341,376
General Partner [Member]
Related Party Transactions [Abstract]
General partnership ownership interest (in hundredths)	2.00%

ACCUMULATED OTHER COMPREHENSI61

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Unrealized gains (losses) on risk management assets/liabilities - January 1	$ (111,357)	$ (91,823)
Unrealized gains (losses) on risk-management assets/liabilities of unconsolidated affiliates - January 1	(1,925)	0
Accumulated other comprehensive loss - January 1	(113,282)	(91,823)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During the Period, Net of Tax	(35,752)	47,500	$ (64,639)
Other Comprehensive Income (Loss), Amount Attributable to Equity Method Investments, before Reclassification Adjustments, Net of Tax	(1,838)	(1,925)
Other comprehensive income (loss) before reclassifications	(37,590)	45,575
Amounts reclassified from accumulated other comprehensive income (loss)	(10,717)	(67,034)	31,653
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI for Other Comprehensive Income Attributable to Equity Method Investments, Net of Tax	63	0
Other Comprehensive Income (Loss), Reclassification Adjustment included in Net Income, Net of Tax	(10,654)	(67,034)	31,653
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	(46,469)	(19,534)
Other comprehensive income (loss) on investments in unconsolidated affiliates	(1,775)	(1,925)	0
Net current-period other comprehensive income (loss) attributable to ONEOK Partners, L.P.	(48,244)	(21,459)	(32,986)
Unrealized gains (losses) on risk management assets/liabilities - December 31	(157,826)	(111,357)	(91,823)
Unrealized gains (losses) on risk-management assets/liabilities of unconsolidated affiliates - December 31	(3,700)	(1,925)	0
Accumulated other comprehensive loss - December 31	(161,526)	(113,282)	(91,823)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Amounts reclassified from accumulated other comprehensive income (loss)	(10,717)	(67,034)	31,653
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Commodity Contract [Member]
Amounts reclassified from accumulated other comprehensive income (loss)	(26,422)	(81,089)	21,052
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Interest Rate Contract [Member]
Amounts reclassified from accumulated other comprehensive income (loss)	15,705	14,055	10,601
Accumulated Other Comprehensive Income from Investments in Unconsolidated Affiliates Attributable to Parent [Member]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI for Other Comprehensive Income Attributable to Equity Method Investments, Net of Tax	$ 63	$ 0	$ 0

LIMITED PARTNERS' NET INCOME 62

LIMITED PARTNERS' NET INCOME PER UNIT (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)Rate	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Number of days notice of withdrawal of waiver (in days)	90
General partnership ownership interest (in hundredths)	41.20%
General Partner [Member]
Incentive Distribution Made to Managing Member or General Partner [Line Items]
General partnership ownership interest (in hundredths)	2.00%
General Partner [Member] | Distributions Declared [Member]
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution allocated to general partner | $	$ 402,152	$ 382,759	$ 326,022

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current income tax provision
Federal	$ 0	$ 0	$ 59
State	1,830	(621)	1,777
Total current income tax provision	1,830	(621)	1,836
Deferred income tax provision
Federal	8,705	5,413	5,033
State	3,365	(648)	5,799
Total deferred income tax provision	12,070	4,765	10,832
Income Tax Reconciliation [Abstract]
Income before income taxes	1,086,164	602,016	924,003
Less: Net income attributable to noncontrolling interests	5,497	8,330	1,037
Income attributable to ONEOK Partners, L.P. before income taxes	$ 1,080,667	$ 593,686	$ 922,966
Federal statutory income tax rate	35.00%	35.00%	35.00%
Provision for federal income taxes	$ 378,233	$ 207,790	$ 323,038
Partnership earnings not subject to tax	(370,059)	(202,143)	(318,021)
State income taxes, net of federal benefit	5,067	(2,078)	7,576
State deferred tax rate change, net of valuation allowance	128	810	0
Other, net	531	(235)	75
Income tax provision	13,900	4,144	$ 12,668
Deferred tax assets
Federal and state net operating loss	8,293	4,224
Other	4	7
Total deferred tax assets	8,297	4,231
Deferred tax liabilities
Excess of tax over book depreciation	83,731	67,265
Regulatory assets	33	49
Total deferred tax liabilities	83,764	67,314
Net deferred tax liabilities	$ 75,467	$ 63,083

UNCONSOLIDATED AFFILIATES (Deta

UNCONSOLIDATED AFFILIATES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 958,807	$ 948,221
Equity Method Goodwill	40,100	40,100
Equity in net earnings from investments	139,690	125,300	$ 117,415
Equity Method Investment, Other than Temporary Impairment	0	(180,583)	(76,412)
Accounts Payable, Related Parties, Current	11,100	8,000
Payments to Acquire Other Investments	68,275	27,540	1,063
Balance Sheet [Abstract]
Current assets	143,317	149,439
Property, plant and equipment, net	2,579,607	2,556,559
Other noncurrent assets	20,784	23,722
Current liabilities	77,388	211,037
Long-term debt	649,539	425,521
Other noncurrent liabilities	69,265	69,356
Accumulated other comprehensive loss	(7,450)	(5,669)
Owners' equity	1,954,966	2,029,475
Income Statement [Abstract]
Operating revenues	578,542	524,496	548,491
Operating expenses	260,753	304,930	309,990
Net income	293,921	200,064	214,410
Equity Method Investment, Dividends or Distributions, Total	196,717	155,918	139,019
Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	140,300	104,700	62,000
Northern Border Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 328,456	$ 363,231
Net ownership percentage	50.00%	50.00%
Equity in net earnings from investments	$ 69,990	$ 66,941	69,819
Overland Pass Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 444,138	$ 459,354
Net ownership percentage	50.00%	50.00%
Equity in net earnings from investments	$ 53,984	$ 37,783	25,906
Other Unconsolidated Affiliate [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	186,213	125,636
Equity in net earnings from investments	$ 15,716	20,576	$ 21,690
Bighorn Gas Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Net ownership percentage	49.00%
Fort Union Gas Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Net ownership percentage	37.00%
Lost Creek Gathering Company [Member]
Schedule of Equity Method Investments [Line Items]
Net ownership percentage	35.00%
Roadrunner Gas Transmission [Member]
Income Statement [Abstract]
Payments to Acquire Equity Method Investments	$ 65,000	$ 30,000
Powder River Basin Other Than Bighorn Gas Gathering [Member]
Income Statement [Abstract]
Equity Method Investment, Underlying Equity In Net Assets	$ 31,100

COMMITMENTS AND CONTINGENCIES65

COMMITMENTS AND CONTINGENCIES (Details) - ONEOK Partners [Member] $ in Millions	Dec. 31, 2016USD ($)
Firm Transportation and Storage Contracts [Abstract]
2,017	$ 51.5
2,018	43
2,019	37.5
2,020	37.1
2,021	23
Thereafter	35
Total	$ 227.1

ACQUISITIONS ACQUISITIONS (Deta

ACQUISITIONS ACQUISITIONS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2014USD ($)Rate
West Texas LPG and Mesquite Systems [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Cash	$ 13,839
Accounts receivable	9,132
Other current assets	3,369
Property, plant and equipment	970,359
Fair value of assets acquired	996,699
Accounts payable	(8,621)
Other liabilities	(10,867)
Total fair value of liabilities acquired	(19,488)
Less: Fair value of noncontrolling interest	(162,438)
Net assets acquired	814,773
Less: cash received	(13,839)
Net cash paid for acquisition	$ 800,934
Acquisition date	Nov. 30, 2014
West Texas LPG Pipeline Limited Partnership [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Business Acquisition, Description of Acquired Entity	80 percent interest
Mesquite Pipeline [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired | Rate	100.00%
Regulated Operation [Member] | West Texas LPG and Mesquite Systems [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Property, plant and equipment	$ 812,716
Nonregulated Operation [Member] | West Texas LPG and Mesquite Systems [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Property, plant and equipment	$ 157,643

SEGMENTS (Details)

SEGMENTS (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Segment Reporting, Disclosure of Major Customers									For the year ended December 31, 2016, we had no single customer from which we received 10 percent or more of our consolidated revenues.	For the year ended December 31, 2015, we had no single customer from which we received 10 percent or more of our consolidated revenues.	For the year ended December 31, 2014, we had no single customer from which we received 10 percent or more of our consolidated revenues.
Revenues	$ 2,653,529	$ 2,357,391	$ 2,133,594	$ 1,773,945	$ 1,930,384	$ 1,898,418	$ 2,127,507	$ 1,804,759	$ 8,918,459	$ 7,761,068	$ 12,191,665
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(6,496,124)	(5,641,052)	(10,088,548)
Operating costs									(727,558)	(692,176)	(669,657)
Equity in net earnings from investments									139,690	125,300	117,415
Other									(1,988)	8,447	(13,265)
Depreciation and amortization									(388,569)	(352,196)	(291,236)
Impairment of long-lived assets									0	(83,673)	0
Impairment of equity method investments									0	(180,583)	(76,412)
Total assets	15,469,347				14,927,586				15,469,347	14,927,586	14,600,400
Capital expenditures									621,722	1,186,123	1,745,990
Net income	278,603	$ 275,411	$ 261,964	$ 256,286	9,565	$ 229,665	$ 211,610	$ 147,032	1,072,264	597,872	911,335
Interest expense, net of capitalized interest									366,789	338,911	281,908
Income taxes									13,900	4,144	12,668
Impairment charges									0	264,256	76,412
Operating Income (Loss)									1,316,124	998,079	1,148,823
Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenues									2,051,577	1,837,116	2,967,608
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(1,331,542)	(1,265,617)	(2,305,723)
Operating costs									(285,599)	(272,418)	(257,658)
Equity in net earnings from investments									10,742	17,863	20,271
Other									1,600	1,610	672
Adjusted EBITDA									446,778	318,554	425,170
Depreciation and amortization									(178,548)	(150,008)	(123,847)
Impairment of long-lived assets										(73,681)
Impairment of equity method investments										(180,583)	(76,412)
Total assets	5,320,666				5,123,450				5,320,666	5,123,450	4,911,283
Capital expenditures									410,485	887,938	898,896
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Revenues									7,675,654	6,579,699	10,545,381
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(6,321,377)	(5,328,256)	(9,435,296)
Operating costs									(327,597)	(314,505)	(296,402)
Equity in net earnings from investments									54,513	38,696	27,326
Other									(1,574)	(3,342)	(87)
Adjusted EBITDA									1,079,619	972,292	840,922
Depreciation and amortization									(163,303)	(158,709)	(124,071)
Impairment of long-lived assets										(9,992)
Impairment of equity method investments										0	0
Total assets	8,347,961				8,017,799				8,347,961	8,017,799	8,143,575
Capital expenditures									105,861	226,135	798,048
Natural Gas Liquids [Member] | Natural Gas Liquids Regulated [Member]
Segment Reporting Information [Line Items]
Revenues									1,175,300	954,800	695,900
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(458,700)	(412,600)	(309,400)
Operating Income (Loss)									467,900	306,900	196,100
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues									379,361	332,447	350,456
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(30,561)	(34,481)	(21,935)
Operating costs									(115,628)	(105,720)	(111,037)
Equity in net earnings from investments									74,435	68,741	69,818
Other									5,530	13,993	6,900
Adjusted EBITDA									313,137	274,980	294,202
Depreciation and amortization									(46,718)	(43,479)	(43,318)
Impairment of long-lived assets										0
Impairment of equity method investments										0	0
Total assets	1,946,318				1,851,857				1,946,318	1,851,857	1,835,884
Capital expenditures									96,274	58,215	42,991
Natural Gas Pipelines [Member] | Natural Gas Pipelines Regulated [Member]
Segment Reporting Information [Line Items]
Revenues									238,700	266,900	290,000
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(30,000)	(31,100)	(47,700)
Operating Income (Loss)									100,800	103,700	106,500
Total Segments [Member]
Segment Reporting Information [Line Items]
Revenues									10,106,592	8,749,262	13,863,445
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									(7,683,480)	(6,628,354)	(11,762,954)
Operating costs									(728,824)	(692,643)	(665,097)
Equity in net earnings from investments									139,690	125,300	117,415
Other									5,556	12,261	7,485
Adjusted EBITDA									1,839,534	1,565,826	1,560,294
Depreciation and amortization									(388,569)	(352,196)	(291,236)
Impairment of long-lived assets										(83,673)
Impairment of equity method investments										(180,583)	(76,412)
Total assets	15,614,945				14,993,106				15,614,945	14,993,106	14,890,742
Capital expenditures									612,620	1,172,288	1,739,935
Other and Eliminations
Segment Reporting Information [Line Items]
Revenues									(1,188,133)	(988,194)	(1,671,780)
Cost of sales and fuel (exclusive of depreciation and items shown separately below)									1,187,356	987,302	1,674,406
Operating costs									1,266	467	(4,560)
Equity in net earnings from investments									0	0	0
Depreciation and amortization									0	0	0
Impairment of long-lived assets										0
Impairment of equity method investments										0	0
Total assets	$ (145,598)				$ (65,520)				(145,598)	(65,520)	(290,342)
Capital expenditures									9,102	13,835	6,055
Unaffiliated entity [Member]
Segment Reporting Information [Line Items]
Revenues									8,918,459	7,761,068	12,138,139
Unaffiliated entity [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenues									1,375,738	1,187,390	1,478,729
Unaffiliated entity [Member] | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Revenues									7,168,983	6,248,002	10,329,609
Unaffiliated entity [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues									373,738	325,676	329,801
Unaffiliated entity [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenues									8,918,459	7,761,068	12,138,139
Unaffiliated entity [Member] | Other and Eliminations
Segment Reporting Information [Line Items]
Revenues									0	0	0
Affiliated Entity [Member]
Segment Reporting Information [Line Items]
Revenues											53,526
Affiliated Entity [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenues											41,214
Affiliated Entity [Member] | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Revenues											0
Affiliated Entity [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues											12,312
Affiliated Entity [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenues											53,526
Affiliated Entity [Member] | Other and Eliminations
Segment Reporting Information [Line Items]
Revenues											0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues									0	0	0
Operating Segments [Member] | Natural Gas Gathering And Processing [Member]
Segment Reporting Information [Line Items]
Revenues									675,839	649,726	1,447,665
Operating Segments [Member] | Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Revenues									506,671	331,697	215,772
Operating Segments [Member] | Natural Gas Liquids [Member] | Natural Gas Liquids Regulated [Member]
Segment Reporting Information [Line Items]
Revenues									992,800	770,100	598,100
Operating Segments [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues									5,623	6,771	8,343
Operating Segments [Member] | Total Segments [Member]
Segment Reporting Information [Line Items]
Revenues									1,188,133	988,194	1,671,780
Operating Segments [Member] | Other and Eliminations
Segment Reporting Information [Line Items]
Revenues									$ (1,188,133)	$ (988,194)	$ (1,671,780)

QUARTERLY FINANCIAL DATA (UNA68

QUARTERLY FINANCIAL DATA (UNAUDITED) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impairment charges									$ 0	$ 264,256	$ 76,412
Revenues	$ 2,653,529	$ 2,357,391	$ 2,133,594	$ 1,773,945	$ 1,930,384	$ 1,898,418	$ 2,127,507	$ 1,804,759	8,918,459	7,761,068	12,191,665
Net income	278,603	275,411	261,964	256,286	9,565	229,665	211,610	147,032	1,072,264	597,872	911,335
Net income attributable to ONEOK Partners, L.P.	$ 277,474	$ 274,308	$ 261,468	$ 253,517	$ 7,217	$ 226,961	$ 209,770	$ 145,594	$ 1,066,767	$ 589,542	$ 910,298
Limited partners' per unit net income (loss)	$ 0.60	$ 0.59	$ 0.54	$ 0.52	$ (0.33)	$ 0.45	$ 0.44	$ 0.21	$ 2.25	$ 0.73	$ 2.33

SUPPLEMENTAL CONDENSED CONSOL69

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION CONDENSED CONSOLIDATING FINANCIAL STATEMENTS, Income Statement (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Commodity sales									$ 6,858,456	$ 6,098,343	$ 10,724,981
Services									2,060,003	1,662,725	1,466,684
Total revenues	$ 2,653,529	$ 2,357,391	$ 2,133,594	$ 1,773,945	$ 1,930,384	$ 1,898,418	$ 2,127,507	$ 1,804,759	8,918,459	7,761,068	12,191,665
Cost of sales and fuel (exclusive of items shown separately below)									6,496,124	5,641,052	10,088,548
Impairment of long-lived assets									0	83,673	0
Operations and maintenance									639,532	609,123	599,076
Depreciation and amortization									388,569	352,196	291,236
General taxes									88,026	83,053	70,581
(Gain) loss on sale of assets									(9,916)	(6,108)	(6,599)
Operating income									1,316,124	998,079	1,148,823
Equity in net earnings from investments									139,690	125,300	117,415
Impairment of equity method investments									0	(180,583)	(76,412)
Interest expense									(366,789)	(338,911)	(281,908)
Income before income taxes									1,086,164	602,016	924,003
Income taxes									(13,900)	(4,144)	(12,668)
Net income	278,603	275,411	261,964	256,286	9,565	229,665	211,610	147,032	1,072,264	597,872	911,335
Less: Net income attributable to noncontrolling interests									5,497	8,330	1,037
Net income attributable to ONEOK Partners, L.P.	$ 277,474	$ 274,308	$ 261,468	$ 253,517	$ 7,217	$ 226,961	$ 209,770	$ 145,594	$ 1,066,767	$ 589,542	910,298
Northern Border Pipeline [Member]
Condensed Financial Statements, Captions [Line Items]
Equity Method Investment, Ownership Percentage	50.00%				50.00%				50.00%	50.00%
Equity in net earnings from investments									$ 69,990	$ 66,941	69,819
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Commodity sales									0	0	0
Services									0	0	0
Total revenues									0	0	0
Cost of sales and fuel (exclusive of items shown separately below)									0	0	0
Impairment of long-lived assets										0
Operating expenses									0	0	0
(Gain) loss on sale of assets									0	0	0
Operating income									0	0	0
Equity in net earnings from investments									(2,063,600)	(1,112,100)	(1,750,800)
Impairment of equity method investments										0	0
Other income (expense), net									(747,000)	(742,000)	(663,400)
Interest expense									747,000	742,000	663,400
Income before income taxes									(2,063,600)	(1,112,100)	(1,750,800)
Income taxes									0	0	0
Net income									(2,063,600)	(1,112,100)	(1,750,800)
Less: Net income attributable to noncontrolling interests									0	0	0
Net income attributable to ONEOK Partners, L.P.									(2,063,600)	(1,112,100)	(1,750,800)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Commodity sales									0	0	0
Services									0	0	0
Total revenues									0	0	0
Cost of sales and fuel (exclusive of items shown separately below)									0	0	0
Impairment of long-lived assets										0
Operating expenses									0	0	0
(Gain) loss on sale of assets									0	0	0
Operating income									0	0	0
Equity in net earnings from investments									1,066,800	589,500	910,300
Impairment of equity method investments										0	0
Other income (expense), net									373,500	371,000	331,700
Interest expense									(373,500)	(371,000)	(331,700)
Income before income taxes									1,066,800	589,500	910,300
Income taxes									0	0	0
Net income									1,066,800	589,500	910,300
Less: Net income attributable to noncontrolling interests									0	0	0
Net income attributable to ONEOK Partners, L.P.									1,066,800	589,500	910,300
Guarantor Subsidiary [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Commodity sales									0	0	0
Services									0	0	0
Total revenues									0	0	0
Cost of sales and fuel (exclusive of items shown separately below)									0	0	0
Impairment of long-lived assets										0
Operating expenses									0	0	0
(Gain) loss on sale of assets									0	0	0
Operating income									0	0	0
Equity in net earnings from investments									1,066,800	589,500	910,300
Impairment of equity method investments										0	0
Other income (expense), net									373,500	371,000	331,700
Interest expense									(373,500)	(371,000)	(331,700)
Income before income taxes									1,066,800	589,500	910,300
Income taxes									0	0	0
Net income									1,066,800	589,500	910,300
Less: Net income attributable to noncontrolling interests									0	0	0
Net income attributable to ONEOK Partners, L.P.									1,066,800	589,500	910,300
Combined Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Commodity sales									6,858,500	6,098,300	10,725,000
Services									2,060,000	1,662,800	1,466,700
Total revenues									8,918,500	7,761,100	12,191,700
Cost of sales and fuel (exclusive of items shown separately below)									6,496,100	5,641,100	10,088,600
Impairment of long-lived assets										83,700
Operating expenses									1,116,200	1,044,300	960,900
(Gain) loss on sale of assets									(9,900)	(6,100)	(6,600)
Operating income									1,316,100	998,100	1,148,800
Equity in net earnings from investments									69,700	58,400	47,600
Impairment of equity method investments										(180,600)	(76,400)
Other income (expense), net									(2,800)	(1,900)	16,100
Interest expense									(366,800)	(338,900)	(281,900)
Income before income taxes									1,016,200	535,100	854,200
Income taxes									(13,900)	(4,100)	(12,700)
Net income									1,002,300	531,000	841,500
Less: Net income attributable to noncontrolling interests									5,500	8,400	1,000
Net income attributable to ONEOK Partners, L.P.									996,800	522,600	840,500
Total [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Commodity sales									6,858,500	6,098,300	10,725,000
Services									2,060,000	1,662,800	1,466,700
Total revenues									8,918,500	7,761,100	12,191,700
Cost of sales and fuel (exclusive of items shown separately below)									6,496,100	5,641,100	10,088,600
Impairment of long-lived assets										83,700
Operating expenses									1,116,200	1,044,300	960,900
(Gain) loss on sale of assets									(9,900)	(6,100)	(6,600)
Operating income									1,316,100	998,100	1,148,800
Equity in net earnings from investments									139,700	125,300	117,400
Impairment of equity method investments										(180,600)	(76,400)
Other income (expense), net									(2,800)	(1,900)	16,100
Interest expense									(366,800)	(338,900)	(281,900)
Income before income taxes									1,086,200	602,000	924,000
Income taxes									(13,900)	(4,100)	(12,700)
Net income									1,072,300	597,900	911,300
Less: Net income attributable to noncontrolling interests									5,500	8,400	1,000
Net income attributable to ONEOK Partners, L.P.									$ 1,066,800	$ 589,500	$ 910,300

SUPPLEMENTAL CONDENSED CONSOL70

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION CONDENSED CONSOLIDATING FINANCIAL INFORMATION, Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net income	$ 278,603	$ 275,411	$ 261,964	$ 256,286	$ 9,565	$ 229,665	$ 211,610	$ 147,032	$ 1,072,264	$ 597,872	$ 911,335
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(35,752)	47,500	(64,639)
Realized (gains) losses on derivatives recognized in net income									(10,717)	(67,034)	31,653
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,775)	(1,925)	0
Total other comprehensive income (loss)									(48,244)	(21,459)	(32,986)
Comprehensive income									1,024,020	576,413	878,349
Less: Comprehensive income attributable to noncontrolling interests									5,497	8,330	1,037
Comprehensive income attributable to ONEOK Partners, L.P.									1,018,523	568,083	877,312
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net income									1,066,800	589,500	910,300
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(35,800)	47,500	(64,600)
Realized (gains) losses on derivatives recognized in net income									(10,700)	(67,000)	31,600
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,800)	(1,900)
Total other comprehensive income (loss)									(48,300)	(21,400)	(33,000)
Comprehensive income									1,018,500	568,100	877,300
Less: Comprehensive income attributable to noncontrolling interests									0	0	0
Comprehensive income attributable to ONEOK Partners, L.P.									1,018,500	568,100	877,300
Reportable Legal Entities [Member] | Guarantor Subsidiary [Member]
Condensed Financial Statements, Captions [Line Items]
Net income									1,066,800	589,500	910,300
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(78,500)	70,100	32,400
Realized (gains) losses on derivatives recognized in net income									(26,400)	(81,100)	21,100
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,800)	(1,900)
Total other comprehensive income (loss)									(106,700)	(12,900)	53,500
Comprehensive income									960,100	576,600	963,800
Less: Comprehensive income attributable to noncontrolling interests									0	0	0
Comprehensive income attributable to ONEOK Partners, L.P.									960,100	576,600	963,800
Reportable Legal Entities [Member] | Combined Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income									1,002,300	531,000	841,500
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(78,500)	70,100	32,400
Realized (gains) losses on derivatives recognized in net income									(26,400)	(81,100)	21,100
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,800)	(1,900)
Total other comprehensive income (loss)									(106,700)	(12,900)	53,500
Comprehensive income									895,600	518,100	895,000
Less: Comprehensive income attributable to noncontrolling interests									5,500	8,400	1,000
Comprehensive income attributable to ONEOK Partners, L.P.									890,100	509,700	894,000
Reportable Legal Entities [Member] | Total [Member]
Condensed Financial Statements, Captions [Line Items]
Net income									1,072,300	597,900	911,300
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									(35,800)	47,500	(64,600)
Realized (gains) losses on derivatives recognized in net income									(10,700)	(67,000)	31,600
Other comprehensive income (loss) on investments in unconsolidated affiliates									(1,800)	(1,900)
Total other comprehensive income (loss)									(48,300)	(21,400)	(33,000)
Comprehensive income									1,024,000	576,500	878,300
Less: Comprehensive income attributable to noncontrolling interests									5,500	8,400	1,000
Comprehensive income attributable to ONEOK Partners, L.P.									1,018,500	568,100	877,300
Consolidating Entries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income									(2,063,600)	(1,112,100)	(1,750,800)
Other comprehensive income (loss)
Unrealized gains (losses) on derivatives									157,000	(140,200)	(64,800)
Realized (gains) losses on derivatives recognized in net income									52,800	162,200	(42,200)
Other comprehensive income (loss) on investments in unconsolidated affiliates									3,600	3,800
Total other comprehensive income (loss)									213,400	25,800	(107,000)
Comprehensive income									(1,850,200)	(1,086,300)	(1,857,800)
Less: Comprehensive income attributable to noncontrolling interests									0	0	0
Comprehensive income attributable to ONEOK Partners, L.P.									$ (1,850,200)	$ (1,086,300)	$ (1,857,800)

SUPPLEMENTAL CONDENSED CONSOL71

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION CONDENSED CONSOLIDATING FINANCIAL STATEMENTS, Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets
Cash and cash equivalents	$ 406	$ 5,079	$ 42,530	$ 134,530
Accounts receivable, net	872,310	593,448
Affiliate receivables	984	7,969
Natural gas and natural gas liquids in storage	140,034	128,084
Commodity imbalances	60,896	38,681
Materials and supplies	60,912	76,696
Other current assets	38,703	33,207
Total current assets	1,174,245	883,164
Property, plant and equipment
Property, plant and equipment	14,854,696	14,307,546
Accumulated depreciation and amortization	2,392,004	2,050,755
Net property, plant and equipment	12,462,692	12,256,791
Investments and other assets
Investments in unconsolidated affiliates	958,807	948,221
Goodwill and intangible assets	812,977	824,877
Other assets	60,626	14,533
Total investments and other assets	1,832,410	1,787,631
Total assets	15,469,347	14,927,586	14,600,400
Current liabilities
Current maturities of long-term debt	407,650	107,650
Short-term borrowings	1,110,277	546,340
Accounts payable	862,436	605,431
Affiliate payables	68,233	27,137
Commodity imbalances	142,646	74,460
Accrued interest	87,130	102,615
Other current liabilities	146,004	116,667
Total current liabilities	2,824,376	1,580,300
Long-term debt, excluding current maturities	6,291,307	6,695,312
Deferred credits and other liabilities	175,844	154,631
Commitments and contingencies
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	6,019,738	6,333,218
Noncontrolling interests in consolidated subsidiaries	158,082	164,125
Total equity	6,177,820	6,497,343
Total liabilities and equity	15,469,347	14,927,586
Reportable Legal Entities [Member] | Parent Company [Member]
Current assets
Cash and cash equivalents	0	0	0	0
Accounts receivable, net	0	0
Affiliate receivables	0	0
Natural gas and natural gas liquids in storage	0	0
Materials and supplies	0	0
Other current assets	0	4,100
Total current assets	0	4,100
Property, plant and equipment
Property, plant and equipment	0	0
Accumulated depreciation and amortization	0	0
Net property, plant and equipment	0	0
Investments and other assets
Intercompany notes receivable	10,615,000	10,144,900
Other assets	3,269,600	3,594,000
Total investments and other assets	13,884,600	13,738,900
Total assets	13,884,600	13,743,000
Current liabilities
Current maturities of long-term debt	400,000	100,000
Short-term borrowings	1,110,300	546,300
Accounts payable	0	0
Affiliate payables	0	0
Other current liabilities	99,900	112,500
Total current liabilities	1,610,200	758,800
Intercompany debt	0	0
Long-term debt, excluding current maturities	6,254,700	6,651,000
Deferred credits and other liabilities	0	0
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	6,019,700	6,333,200
Noncontrolling interests in consolidated subsidiaries	0	0
Total equity	6,019,700	6,333,200
Total liabilities and equity	13,884,600	13,743,000
Reportable Legal Entities [Member] | Guarantor Subsidiary [Member]
Current assets
Cash and cash equivalents	400	5,100	42,500	134,500
Accounts receivable, net	0	0
Affiliate receivables	0	0
Natural gas and natural gas liquids in storage	0	0
Materials and supplies	0	0
Other current assets	0	0
Total current assets	400	5,100
Property, plant and equipment
Property, plant and equipment	0	0
Accumulated depreciation and amortization	0	0
Net property, plant and equipment	0	0
Investments and other assets
Intercompany notes receivable	7,031,300	7,781,800
Other assets	6,805,400	5,952,000
Total investments and other assets	13,836,700	13,733,800
Total assets	13,837,100	13,738,900
Current liabilities
Current maturities of long-term debt	0	0
Short-term borrowings	0	0
Accounts payable	0	0
Affiliate payables	0	0
Other current liabilities	0	0
Total current liabilities	0	0
Intercompany debt	10,615,000	10,144,900
Long-term debt, excluding current maturities	0	0
Deferred credits and other liabilities	0	0
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	3,222,100	3,594,000
Noncontrolling interests in consolidated subsidiaries	0	0
Total equity	3,222,100	3,594,000
Total liabilities and equity	13,837,100	13,738,900
Reportable Legal Entities [Member] | Combined Non-Guarantor Subsidiaries [Member]
Current assets
Cash and cash equivalents	0	0	0	0
Accounts receivable, net	872,300	593,400
Affiliate receivables	1,000	8,000
Natural gas and natural gas liquids in storage	140,000	128,100
Materials and supplies	60,900	76,700
Other current assets	99,600	67,800
Total current assets	1,173,800	874,000
Property, plant and equipment
Property, plant and equipment	14,854,700	14,307,500
Accumulated depreciation and amortization	2,392,000	2,050,700
Net property, plant and equipment	12,462,700	12,256,800
Investments and other assets
Intercompany notes receivable	0	0
Other assets	1,457,200	1,425,200
Total investments and other assets	1,457,200	1,425,200
Total assets	15,093,700	14,556,000
Current liabilities
Current maturities of long-term debt	7,700	7,700
Short-term borrowings	0	0
Accounts payable	862,400	605,400
Affiliate payables	68,200	27,100
Other current liabilities	275,900	181,400
Total current liabilities	1,214,200	821,600
Intercompany debt	7,031,300	7,781,800
Long-term debt, excluding current maturities	36,600	44,300
Deferred credits and other liabilities	175,800	154,600
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	6,477,700	5,589,600
Noncontrolling interests in consolidated subsidiaries	158,100	164,100
Total equity	6,635,800	5,753,700
Total liabilities and equity	15,093,700	14,556,000
Reportable Legal Entities [Member] | Total [Member]
Current assets
Cash and cash equivalents	400	5,100	42,500	134,500
Accounts receivable, net	872,300	593,400
Affiliate receivables	1,000	8,000
Natural gas and natural gas liquids in storage	140,000	128,100
Materials and supplies	60,900	76,700
Other current assets	99,600	71,900
Total current assets	1,174,200	883,200
Property, plant and equipment
Property, plant and equipment	14,854,700	14,307,500
Accumulated depreciation and amortization	2,392,000	2,050,700
Net property, plant and equipment	12,462,700	12,256,800
Investments and other assets
Intercompany notes receivable	0	0
Other assets	1,832,400	1,787,600
Total investments and other assets	1,832,400	1,787,600
Total assets	15,469,300	14,927,600
Current liabilities
Current maturities of long-term debt	407,700	107,700
Short-term borrowings	1,110,300	546,300
Accounts payable	862,400	605,400
Affiliate payables	68,200	27,100
Other current liabilities	375,800	293,900
Total current liabilities	2,824,400	1,580,400
Intercompany debt	0	0
Long-term debt, excluding current maturities	6,291,300	6,695,300
Deferred credits and other liabilities	175,800	154,600
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	6,019,700	6,333,200
Noncontrolling interests in consolidated subsidiaries	158,100	164,100
Total equity	6,177,800	6,497,300
Total liabilities and equity	15,469,300	14,927,600
Consolidating Entries [Member]
Current assets
Cash and cash equivalents	0	0	$ 0	$ 0
Accounts receivable, net	0	0
Affiliate receivables	0	0
Natural gas and natural gas liquids in storage	0	0
Materials and supplies	0	0
Other current assets	0	0
Total current assets	0	0
Property, plant and equipment
Property, plant and equipment	0	0
Accumulated depreciation and amortization	0	0
Net property, plant and equipment	0	0
Investments and other assets
Intercompany notes receivable	(17,646,300)	(17,926,700)
Other assets	(9,699,800)	(9,183,600)
Total investments and other assets	(27,346,100)	(27,110,300)
Total assets	(27,346,100)	(27,110,300)
Current liabilities
Current maturities of long-term debt	0	0
Short-term borrowings	0	0
Accounts payable	0	0
Affiliate payables	0	0
Other current liabilities	0	0
Total current liabilities	0	0
Intercompany debt	(17,646,300)	(17,926,700)
Long-term debt, excluding current maturities	0	0
Deferred credits and other liabilities	0	0
Equity
Equity excluding noncontrolling interests in consoldated subsidiaries	(9,699,800)	(9,183,600)
Noncontrolling interests in consolidated subsidiaries	0	0
Total equity	(9,699,800)	(9,183,600)
Total liabilities and equity	$ (27,346,100)	$ (27,110,300)

SUPPLEMENTAL CONDENSED CONSOL72

SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION CONDENSED CONSOLIDATING FINANCIAL STATEMENTS, Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating activities
Cash provided by operating activities	$ 1,486,777	$ 1,071,980	$ 1,309,820
Investing activities
Acquisitions	0	0	(814,934)
Payments to Acquire Other Investments	(68,275)	(27,540)	(1,063)
Distributions received from unconsolidated affiliates in excess of cumulative earnings	52,044	33,915	21,107
Capital expenditures	(621,722)	(1,186,123)	(1,745,990)
Other investing activities	0	(12,607)	0
Cash provided by (used in) investing activities	(612,594)	(1,188,530)	(2,533,063)
Financing activities
Cash distributions paid to general and limited partners	(1,332,003)	(1,230,475)	(1,052,245)
Cash distributions: Noncontrolling interests	(7,500)	(11,690)	(549)
Borrowing (repayment) of short-term borrowings, net	563,937	(508,956)	1,055,296
Issuance of long-term debt, net of discounts	1,000,000	798,896	0
Debt financing costs	(2,770)	(7,676)	0
Repayments of long-term debt	(1,107,650)	(7,650)	(7,650)
Other	7,130	0	0
Issuance of common units, net of issuance costs	0	1,025,660	1,113,139
Contribution from general partner	0	20,990	23,252
Cash provided by (used in) financing activities	(878,856)	79,099	1,131,243
Change in cash and cash equivalents	(4,673)	(37,451)	(92,000)
Cash and cash equivalents at beginning of period	5,079	42,530	134,530
Cash and cash equivalents at end of period	406	5,079	42,530
Consolidating Entries [Member]
Operating activities
Cash provided by operating activities	(1,332,000)	(1,230,500)	(1,052,200)
Investing activities
Capital expenditures	0	0	0
Other investing activities	0	0	0
Cash provided by (used in) investing activities	0	0	0
Financing activities
Cash distributions paid to general and limited partners	1,332,000	1,230,500	1,052,200
Cash distributions: Noncontrolling interests	0	0	0
Intercompany borrowings (advances), net	0	0	0
Borrowing (repayment) of short-term borrowings, net	0	0	0
Issuance of long-term debt, net of discounts	0	0
Debt financing costs	0	0
Repayments of long-term debt	0	0	0
Other	0
Issuance of common units, net of issuance costs		0	0
Contribution from general partner		0	0
Cash provided by (used in) financing activities	1,332,000	1,230,500	1,052,200
Change in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	0	0	0
Reportable Legal Entities [Member] | Parent Company [Member]
Operating activities
Cash provided by operating activities	1,334,500	1,196,700	1,155,700
Investing activities
Capital expenditures	0	0	0
Other investing activities	0	0	0
Cash provided by (used in) investing activities	0	0	0
Financing activities
Cash distributions paid to general and limited partners	(1,332,000)	(1,230,500)	(1,052,200)
Cash distributions: Noncontrolling interests	0	0	0
Intercompany borrowings (advances), net	(470,800)	(1,295,100)	(2,295,200)
Borrowing (repayment) of short-term borrowings, net	563,900	(509,000)	1,055,300
Issuance of long-term debt, net of discounts	1,000,000	798,900
Debt financing costs	(2,800)	(7,700)
Repayments of long-term debt	(1,100,000)	0	0
Other	7,200
Issuance of common units, net of issuance costs		1,025,700	1,113,100
Contribution from general partner		21,000	23,300
Cash provided by (used in) financing activities	(1,334,500)	(1,196,700)	(1,155,700)
Change in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	0	0	0
Reportable Legal Entities [Member] | Guarantor Subsidiary [Member]
Operating activities
Cash provided by operating activities	70,000	66,900	69,800
Investing activities
Capital expenditures	0	0	0
Other investing activities	34,900	24,100	17,700
Cash provided by (used in) investing activities	34,900	24,100	17,700
Financing activities
Cash distributions paid to general and limited partners	(1,332,000)	(1,230,500)	(1,052,200)
Cash distributions: Noncontrolling interests	0	0	0
Intercompany borrowings (advances), net	1,222,400	1,102,100	872,700
Borrowing (repayment) of short-term borrowings, net	0	0	0
Issuance of long-term debt, net of discounts	0	0
Debt financing costs	0	0
Repayments of long-term debt	0	0	0
Other	0
Issuance of common units, net of issuance costs		0	0
Contribution from general partner		0	0
Cash provided by (used in) financing activities	(109,600)	(128,400)	(179,500)
Change in cash and cash equivalents	(4,700)	(37,400)	(92,000)
Cash and cash equivalents at beginning of period	5,100	42,500	134,500
Cash and cash equivalents at end of period	400	5,100	42,500
Reportable Legal Entities [Member] | Combined Non-Guarantor Subsidiaries [Member]
Operating activities
Cash provided by operating activities	1,414,300	1,038,900	1,136,500
Investing activities
Capital expenditures	(621,700)	(1,186,100)	(1,746,000)
Other investing activities	(25,800)	(26,500)	(804,700)
Cash provided by (used in) investing activities	(647,500)	(1,212,600)	(2,550,700)
Financing activities
Cash distributions paid to general and limited partners	0	0	0
Cash distributions: Noncontrolling interests	(7,500)	(11,700)	(600)
Intercompany borrowings (advances), net	(751,600)	193,000	1,422,500
Borrowing (repayment) of short-term borrowings, net	0	0	0
Issuance of long-term debt, net of discounts	0	0
Debt financing costs	0	0
Repayments of long-term debt	(7,700)	(7,600)	(7,700)
Other	0
Issuance of common units, net of issuance costs		0	0
Contribution from general partner		0	0
Cash provided by (used in) financing activities	(766,800)	173,700	1,414,200
Change in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	0	0	0
Reportable Legal Entities [Member] | Total [Member]
Operating activities
Cash provided by operating activities	1,486,800	1,072,000	1,309,800
Investing activities
Capital expenditures	(621,700)	(1,186,100)	(1,746,000)
Other investing activities	9,100	(2,400)	(787,000)
Cash provided by (used in) investing activities	(612,600)	(1,188,500)	(2,533,000)
Financing activities
Cash distributions paid to general and limited partners	(1,332,000)	(1,230,500)	(1,052,200)
Cash distributions: Noncontrolling interests	(7,500)	(11,700)	(600)
Intercompany borrowings (advances), net	0	0	0
Borrowing (repayment) of short-term borrowings, net	563,900	(509,000)	1,055,300
Issuance of long-term debt, net of discounts	1,000,000	798,900
Debt financing costs	(2,800)	(7,700)
Repayments of long-term debt	(1,107,700)	(7,600)	(7,700)
Other	7,200
Issuance of common units, net of issuance costs		1,025,700	1,113,100
Contribution from general partner		21,000	23,300
Cash provided by (used in) financing activities	(878,900)	79,100	1,131,200
Change in cash and cash equivalents	(4,700)	(37,400)	(92,000)
Cash and cash equivalents at beginning of period	5,100	42,500	134,500
Cash and cash equivalents at end of period	$ 400	$ 5,100	$ 42,500