Tallgrass Energy 10-Q 30 Oct 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 30, 2019
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
Document Transition Report	false
Entity File Number	001-37365
Entity Registrant Name	Tallgrass Energy, LP
City Area Code	913
Local Phone Number	928-6060
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	47-3159268
Entity Address, Address Line One	4200 W. 115th Street, Suite 350
Entity Address, City or Town	Leawood,
Entity Address, State or Province	KS
Entity Address, Postal Zip Code	66211
Title of 12(b) Security	Class A Shares Representing Limited Partner Interests
Trading Symbol	TGE
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001633651
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Amendment Flag	false
Common Class A
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		179,197,416
Common Class B
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		102,136,875

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 15,967	$ 9,596
Receivables, Net, Current	246,293	236,097
Inventories	41,028	34,316
Prepayments and other current assets	14,785	11,816
Total Current Assets	318,073	291,825
Property, plant and equipment, net	2,865,107	2,802,429
Goodwill	441,361	421,983
Intangible assets, net	246,684	227,103
Unconsolidated investments	1,964,949	1,861,686
Deferred tax asset	334,970	273,531
Deferred charges and other assets	31,753	14,952
Total Assets	6,202,897	5,893,509
Current Liabilities:
Accounts payable	196,033	201,512
Accrued taxes	28,427	20,734
Accrued interest	24,012	39,217
Accrued liabilities	21,795	23,287
Deferred revenue	125,198	111,095
Other current liabilities	41,759	42,910
Total Current Liabilities	437,224	438,755
Long-term debt, net	3,451,268	3,205,958
Other long-term liabilities and deferred credits	53,357	31,688
Total Long-term Liabilities	3,504,625	3,237,646
Commitments and Contingencies
Equity [Abstract]
Total Partners' Equity	1,848,872	1,725,537
Noncontrolling interests (a)	412,176	491,571
Total Equity	2,261,048	2,217,108
Total Liabilities and Equity	6,202,897	5,893,509
Common Class A
Equity [Abstract]
Total Partners' Equity	1,848,872	1,725,537
Common Class B
Equity [Abstract]
Total Partners' Equity	$ 0	$ 0

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2019	Dec. 31, 2018
Common Class A
Shares, Outstanding	179,197,416	156,311,986
Common Class B
Shares, Outstanding	102,136,875	123,887,893

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues:
Total Revenues	$ 226,709,000	$ 200,320,000	$ 635,585,000	$ 573,003,000
Operating Costs and Expenses:
Operations and maintenance	22,657,000	18,011,000	64,175,000	52,850,000
Depreciation and amortization	31,797,000	27,595,000	95,778,000	81,408,000
General and administrative	21,439,000	16,015,000	72,426,000	53,526,000
Taxes, other than income taxes	8,183,000	7,750,000	26,892,000	25,091,000
(Gain) loss on disposal of assets	0	279,000	(242,000)	9,417,000
Total Operating Costs and Expenses	120,843,000	110,236,000	369,659,000	321,731,000
Operating Income	105,866,000	90,084,000	265,926,000	251,272,000
Other Income (Expense):
Equity in earnings of unconsolidated investments	86,349,000	76,268,000	273,883,000	222,857,000
Interest expense, net	(41,625,000)	(34,019,000)	(121,925,000)	(95,062,000)
Other income (expense), net	476,000	(1,624,000)	851,000	(843,000)
Total Other Income (Expense)	45,200,000	40,625,000	152,809,000	126,952,000
Net income before tax	151,066,000	130,709,000	418,735,000	378,224,000
Income tax expense	(22,577,000)	(11,997,000)	(61,624,000)	(35,498,000)
Net income	128,489,000	118,712,000	357,111,000	342,726,000
Net income attributable to noncontrolling interests	(55,965,000)	(59,162,000)	(162,381,000)	(265,378,000)
Net income attributable to TGE	$ 72,524,000	$ 59,550,000	$ 194,730,000	$ 77,348,000
Earnings Per Share, Basic and Diluted [Abstract]
Basic net income per Class A share	$ 0.40	$ 0.38	$ 1.12	$ 0.85
Diluted net income per Class A share	$ 0.40	$ 0.38	$ 1.12	$ 0.85
Basic average number of Class A shares outstanding	179,197	155,001	173,322	91,183
Diluted average number of Class A shares outstanding	180,155	156,088	174,756	92,661
Crude oil transportation services
Revenues:
Total Revenues	$ 112,126,000	$ 100,226,000	$ 306,738,000	$ 286,130,000
Natural gas transportation services
Revenues:
Total Revenues	30,312,000	30,953,000	96,173,000	94,623,000
Sales of natural gas, NGLs, and crude oil
Revenues:
Total Revenues	39,902,000	44,072,000	116,609,000	119,467,000
Processing and other revenues
Revenues:
Total Revenues	44,369,000	25,069,000	116,065,000	72,783,000
Cost of sales
Operating Costs and Expenses:
Cost of sales and transportation services	17,664,000	28,556,000	56,217,000	82,601,000
Cost of transportation services
Operating Costs and Expenses:
Cost of sales and transportation services	$ 19,103,000	$ 12,588,000	$ 53,929,000	$ 35,672,000

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) - USD ($)	Total	Tallgrass Energy Partners, LP	Tallgrass Pony Express Pipeline, LLC	Rockies Express Pipeline LLC	CES Holding Company, Inc.	Noncontrolling Interest	Noncontrolling InterestTallgrass Energy Partners, LP	Noncontrolling InterestTallgrass Pony Express Pipeline, LLC	Noncontrolling InterestRockies Express Pipeline LLC	Noncontrolling InterestCES Holding Company, Inc.	Common Class A	Common Class ATallgrass Energy Partners, LP	Common Class ATallgrass Pony Express Pipeline, LLC	Common Class ARockies Express Pipeline LLC	Common Class ACES Holding Company, Inc.	Common Class B	Common Class BTallgrass Energy Partners, LP	Common Class BTallgrass Pony Express Pipeline, LLC	Common Class BRockies Express Pipeline LLC	Common Class BCES Holding Company, Inc.
Increase (Decrease) in Partners' Capital [Roll Forward]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,721,179,000					$ 1,672,566,000					$ 48,613,000					$ 0
Net income	114,313,000					97,578,000					16,735,000					0
Dividends paid to Class A shareholders	(21,346,000)					0					(21,346,000)					0
Distributions to noncontrolling interests	(89,073,000)					(89,073,000)					0					0
Contributions from noncontrolling interests	183,000					183,000					0					0
Noncash compensation expense	(3,322,000)					(2,917,000)					(405,000)					0
Noncontrolling Interest, Increase from Business Combination	31,843,000					31,843,000					0					0
Issuance of TEP units to the public, net of offering costs		$ (45,000)					$ (40,000)					$ (5,000)					$ 0
Acquisition of additional TEP common units from TD		251,743,000					189,520,000					62,223,000					0
Issuance of Tallgrass Equity units	644,782,000					644,782,000					0					0
Acquisitions			$ (50,000,000)	$ 108,537,000				$ (44,732,000)	$ 74,421,000				$ (5,268,000)	$ 34,116,000				$ 0	$ 0
Net income	342,726,000
Distributions to noncontrolling interests	(4,600,000)					(262,900,000)
Contributions from noncontrolling interests						200,000
Acquisitions			$ 16,200,000	$ 108,500,000
Other Significant Noncash Transaction, Value of Consideration Given	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,256,083,000					2,240,468,000					15,615,000					0
Net income	109,701,000					108,638,000					1,063,000					0
Dividends paid to Class A shareholders	(28,316,000)					0					(28,316,000)					0
Distributions to noncontrolling interests	(109,764,000)					(109,764,000)					0					0
Noncash compensation expense	(206,000)					(280,000)					74,000					0
LTIP shares tendered by employees to satisfy tax withholding obligations		(1,721,000)					(1,531,000)					(190,000)					0
Deferred tax asset	7,664,000					0					7,664,000					0
Conversion of Class B shares to Class A shares	0					13,402,000					(13,402,000)					0
Issuance of TEP units to the public, net of offering costs		(203,000)					(181,000)					(22,000)					0
Other Significant Noncash Transaction, Value of Consideration Given	(2,113,758,000)					(1,762,327,000)					(351,431,000)					0
Issuance of Class A shares	2,113,758,000					0					2,113,758,000					0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,233,650,000					488,985,000					1,744,665,000					0
Net income	118,712,000					59,162,000					59,550,000					0
Dividends paid to Class A shareholders	(77,052,000)					0					(77,052,000)					0
Distributions to noncontrolling interests	(64,019,000)					(64,019,000)					0					0
Noncash compensation expense	(2,047,000)					0					(2,047,000)					0
Deferred tax asset	5,839,000					0					5,839,000					0
Conversion of Class B shares to Class A shares	0					(3,267,000)					3,267,000					0
Issuance of TEP units to the public, net of offering costs		$ (129,000)					$ (58,000)					$ (71,000)					$ 0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,219,048,000					480,803,000					1,738,245,000					0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,217,108,000					491,571,000					1,725,537,000					0
Net income	102,392,000					51,805,000					50,587,000					0
Dividends paid to Class A shareholders	(81,304,000)					0					(81,304,000)					0
Distributions to noncontrolling interests	(66,625,000)					(66,625,000)					0					0
Contributions from noncontrolling interests	1,282,000					1,282,000					0					0
Noncash compensation expense	17,120,000					0					(17,120,000)					0
LTIP shares tendered by employees to satisfy tax withholding obligations	(13,260,000)					0					(13,260,000)					0
Deferred tax asset	123,051,000					0					123,051,000					0
Conversion of Class B shares to Class A shares	0					(68,614,000)					68,614,000					0
Net income	357,111,000
Distributions to noncontrolling interests	(5,200,000)					(178,900,000)
Contributions from noncontrolling interests						2,300,000
Other Significant Noncash Transaction, Value of Consideration Given	(122,504,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,299,764,000					409,419,000					1,890,345,000					0
Net income	126,230,000					54,611,000					71,619,000					0
Dividends paid to Class A shareholders	(94,975,000)					0					(94,975,000)					0
Distributions to noncontrolling interests	(55,870,000)					(55,870,000)					0					0
Noncash compensation expense	3,450,000					0					(3,450,000)					0
Acquisitions					$ 3,400,000					$ 3,400,000					$ 0					$ 0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,281,999,000					411,560,000					1,870,439,000					0
Net income	128,489,000					55,965,000					72,524,000					0
Dividends paid to Class A shareholders	(96,767,000)					0					(96,767,000)					0
Distributions to noncontrolling interests	(56,390,000)					(56,390,000)					0					0
Contributions from noncontrolling interests	1,041,000					1,041,000					0					0
Noncash compensation expense	(2,676,000)					0					(2,676,000)					0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 2,261,048,000					$ 412,176,000					$ 1,848,872,000					$ 0

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash Flows from Operating Activities:
Net income	$ 357,111	$ 342,726
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	100,818	86,121
Equity in earnings of unconsolidated investments	(273,883)	(222,857)
Distributions from unconsolidated investments	274,511	222,082
Deferred income tax expense	61,386	35,498
Noncash compensation expense	23,246	6,770
Other noncash items, net	107	(11,451)
Changes in components of working capital
Accounts receivable and other	(12,406)	(115,330)
Accounts payable and accrued liabilities	(8,287)	104,920
Deferred revenue	14,139	14,265
Other current assets and liabilities	9,136	(1,682)
Other operating, net	(9,398)	1,965
Net Cash Provided by Operating Activities	518,208	466,391
Cash Flows from Investing Activities:
Capital expenditures	(225,462)	(265,073)
Distributions from unconsolidated investments in excess of cumulative earnings	95,179	60,720
Contributions to unconsolidated investments	(75,179)	(444,788)
Sale of Tallgrass Crude Gathering	0	50,046
Other investing, net	(42)	(12,304)
Net Cash Provided by (Used in) Investing Activities	(290,920)	(756,499)
Net Cash Used in Financing Activities
Dividends paid to Class A shareholders	(273,046)	(126,714)
Borrowings under revolving credit facilities, net	243,000	244,000
Distributions to noncontrolling interests	178,885	262,856
TGE LTIP shares tendered by employees to satisfy tax withholding obligations	(13,260)	0
Proceeds from Issuance of Senior Long-term Debt	0	500,000
Acquisition of Pony Express membership interest	0	(50,000)
Other financing, net	1,274	(11,394)
Net Cash Used in Financing Activities	(220,917)	293,036
Net Change in Cash and Cash Equivalents
Net Change in Cash and Cash Equivalents	6,371	2,928
Cash and Cash Equivalents, beginning of period	9,596	2,593
Cash and Cash Equivalents, end of period	15,967	5,521
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	(122,504)	0
Accruals for property, plant and equipment	13,134	8,517
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	10,045	0
Shares Issued	0	644,782
Issuance of Noncontrolling Interest in Subsidiary in Exchange for Membership Interest	0	31,843
Noncash Acquisition, Contribution of membership interest	0	(19,500)
Common Class A
Supplemental Cash Flow Disclosures
Shares Issued	0	2,113,758
Powder River Gateway
Cash Flows from Investing Activities:
Contributions to unconsolidated investments	(37,000)	0
Pawnee Terminal, LLC
Cash Flows from Investing Activities:
Contributions to unconsolidated investments	0	(30,600)
Deeprock North, LLC
Cash Flows from Investing Activities:
Contributions to unconsolidated investments	0	(19,500)
Rockies Express Pipeline LLC
Adjustments to reconcile net income to net cash flows provided by operating activities:
Equity in earnings of unconsolidated investments	(267,200)
Cash Flows from Investing Activities:
Contributions to unconsolidated investments	(49,900)
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	0	(393,039)
CES Holding Company, Inc.
Cash Flows from Investing Activities:
Payments to Acquire Businesses, Net of Cash Acquired	(48,416)	0
BNN North Dakota
Cash Flows from Investing Activities:
Payments to Acquire Businesses, Net of Cash Acquired	0	(95,000)
Tallgrass Energy Partners, LP
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	$ 0	$ (2,365,501)

Description of Business

Description of Business	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business	Tallgrass Energy, LP ("TGE"), is a limited partnership that owns, operates, acquires and develops midstream energy assets in North America and has elected to be treated as a corporation for U.S. federal income tax purposes. "We," "us," "our" and similar terms refer to TGE together with its consolidated subsidiaries. Our operations are conducted through, and our operating assets are owned by, our direct and indirect subsidiaries, including Tallgrass Equity, LLC ("Tallgrass Equity"), in which we directly own an approximate 63.70% membership interest as of September 30, 2019 , and Tallgrass Energy Partners, LP ("TEP"), a wholly-owned subsidiary of Tallgrass Equity and its subsidiaries. We are located in and provide services to certain key United States hydrocarbon basins, including the Denver-Julesburg, Powder River, Wind River, Permian and Hugoton-Anadarko Basins and the Niobrara, Mississippi Lime, Eagle Ford, Bakken, Marcellus, and Utica shale formations. Our reportable business segments are: • Natural Gas Transportation—the ownership and operation of FERC-regulated interstate natural gas pipelines and an integrated natural gas storage facility; • Crude Oil Transportation—the ownership and operation of FERC-regulated crude oil pipeline systems; and • Gathering, Processing & Terminalling—the ownership and operation of natural gas gathering and processing facilities; crude oil storage and terminalling facilities; the provision of water business services primarily to the oil and gas exploration and production industry; the transportation of NGLs; and the marketing of crude oil and NGLs. Natural Gas Transportation. We provide natural gas transportation and storage services for customers in the Rocky Mountain, Midwest and Appalachian regions of the United States through: (1) our 75% membership interest in Rockies Express Pipeline LLC ("Rockies Express"), which owns the Rockies Express Pipeline, a FERC-regulated natural gas pipeline system extending from Opal, Wyoming and Meeker, Colorado to Clarington, Ohio (the "Rockies Express Pipeline"), and our 100% membership interest in Tallgrass NatGas Operator, LLC ("NatGas"), which operates the Rockies Express Pipeline, (2) the Tallgrass Interstate Gas Transmission system, a FERC-regulated natural gas transportation and storage system located in Colorado, Kansas, Missouri, Nebraska and Wyoming (the "TIGT System"), and (3) the Trailblazer Pipeline system, a FERC-regulated natural gas pipeline system extending from the Colorado and Wyoming border to Beatrice, Nebraska (the "Trailblazer Pipeline"). Crude Oil Transportation. We provide crude oil transportation to customers in Wyoming, Colorado, Kansas, and the surrounding regions through (1) Tallgrass Pony Express Pipeline, LLC ("Pony Express"), which owns a FERC-regulated crude oil pipeline commencing in both Guernsey, Wyoming and Weld County, Colorado and terminating in Cushing, Oklahoma (the "Pony Express System") and (2) our 51% membership interest in Powder River Gateway, LLC ("Powder River Gateway"), which owns the Powder River Express Pipeline ("PRE Pipeline"), a 70 -mile FERC-regulated crude oil pipeline that transports crude oil from the Powder River Basin to Guernsey, Wyoming, the Iron Horse Pipeline ("Iron Horse Pipeline"), a 80 -mile FERC-regulated crude oil pipeline placed into service in May 2019 that transports crude oil from the Powder River Basin to Guernsey, Wyoming, and crude oil terminal facilities in Guernsey, Wyoming. Gathering, Processing & Terminalling. We provide natural gas gathering and processing services for customers in Wyoming through (collectively, the "Midstream Facilities"): (1) a natural gas gathering system in the Powder River Basin (the "Douglas Gathering System"), (2) natural gas processing facilities in Casper and Douglas, and (3) a natural gas treating facility at West Frenchie Draw. We also provide NGL transportation services in Northeast Colorado and Wyoming. We perform water business services, including freshwater transportation and produced water gathering and disposal, in Colorado, Texas, Wyoming, North Dakota, and Ohio through BNN Water Solutions, LLC ("Water Solutions"), and crude oil storage and terminalling services through our 100% membership interest in Tallgrass Terminals, LLC ("Terminals"), which owns and operates crude oil terminals in Colorado, Oklahoma, and Kansas . The Gathering, Processing & Terminalling segment also includes Stanchion Energy, LLC ("Stanchion"), which transacts in crude oil. Blackstone Acquisition On March 11, 2019, pursuant to the terms of a previously announced definitive purchase agreement (the "Purchase Agreement"), dated January 30, 2019, entered into among acquisition vehicles controlled by affiliates of Blackstone Infrastructure Partners ("BIP" and, acquisition vehicles controlled by BIP, collectively, the "Sponsor Entities"), affiliates of Kelso & Co., affiliates of The Energy & Minerals Group, Tallgrass KC, LLC, an entity owned by certain members of our management, and the other sellers named therein (collectively, the "Sellers"), certain of the Sponsor Entities acquired from the Sellers (i) 100% of the membership interests in our general partner, (ii) 21,751,018 Class A shares representing limited partner interests ("Class A shares") in us, (iii) 100,655,121 units representing limited liability company interests ("TE Units") in Tallgrass Equity, and (iv) 100,655,121 Class B shares representing limited partner interests ("Class B shares") in us, in exchange for aggregate consideration of approximately $3.2 billion in cash, which was paid to the Sellers (the "Blackstone Acquisition"). As a result of the Blackstone Acquisition, BIP effectively controls our business and affairs through the ownership of 100% of the membership interests in our general partner and the exercise of the rights of such sole member. Additionally, the Sponsor Entities collectively held an approximate 44.2% economic interest in us as of September 30, 2019 . Take Private Proposal On August 27, 2019, the board of directors of our general partner received a non-binding preliminary proposal letter from the Sponsor Entities to acquire all of our outstanding Class A shares not already owned by the Sponsor Entities for $19.50 per Class A share (the "Proposal"). The Proposal continues to be reviewed, evaluated and negotiated by members of an independent conflicts committee of the board of directors of our general partner.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Basis of Presentation These condensed consolidated financial statements and related notes for the three and nine months ended September 30, 2019 and 2018 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board's Accounting Standards Codification, the single source of accounting principles generally accepted in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP for annual periods. The condensed consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair statement of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Our financial results for the three and nine months ended September 30, 2019 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2019 . The accompanying condensed consolidated interim financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018 ("2018 Form 10-K") filed with the SEC on February 8, 2019. The condensed consolidated financial statements include the accounts of TGE and its subsidiaries and controlled affiliates. Intra-entity items have been eliminated in the presentation. Net income or loss from consolidated subsidiaries that are not wholly-owned by TGE is attributed to TGE and noncontrolling interests in accordance with the respective ownership interests. We have no elements of other comprehensive income for the periods presented. Use of Estimates Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Income Taxes During the nine months ended September 30, 2019 , we recognized an additional deferred tax asset of $123.1 million upon exercise of the Exchange Right, as discussed in Note 11 – Partnership Equity , with respect to 21,751,018 Class B shares to Class A shares in connection with the Blackstone Acquisition discussed in Note 1 – Description of Business . As a result of the increased income allocated to TGE resulting from our increased ownership in TEP following the merger transaction effective June 30, 2018 and the exercise of the Exchange Right effective March 11, 2019, our annual effective tax rate increased from 9.02% for the nine months ended September 30, 2018 to 14.79% for the nine months ended September 30, 2019 . As discussed in Note 3 – Acquisitions , a newly formed indirect subsidiary of TGE acquired the outstanding stock of an entity classified as a C corporation for U.S. federal income tax purposes effective May 1, 2019. As a result, we recognized approximately $237,000 of current income taxes during the three months ended September 30, 2019 . Accounting Pronouncement Recently Adopted ASU No. 2016-02, "Leases (Topic 842)" In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). ASU 2016-02 provides a comprehensive update to the lease accounting topic in the Codification intended to increase transparency and comparability among organizations by recognizing right-of-use ("ROU") assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The amendments in ASU 2016-02 include a revised definition of a lease as well as certain scope exceptions. The changes primarily impact lessee accounting, while lessor accounting is largely unchanged from previous GAAP. Management has completed its evaluation and implemented the revised guidance using the modified retrospective method as of January 1, 2019. This approach allows us to (i) initially apply ASC 842 at the adoption date, January 1, 2019 and (ii) continue reporting comparative periods presented in the financial statements in the period of adoption under ASC 840. Accordingly, we will not recast comparative periods in the condensed consolidated financial statements. We have elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed us to carry forward the historical lease classification. We have also elected the following practical expedients: (a) the land easement practical expedient, allowing us to carry forward our accounting treatment for existing land easements as property, plant and equipment, (b) the practical expedient for short-term leases, allowing us to not recognize ROU assets or lease liabilities for leases with a term of 12 months or less, and (c) for agreements that contain both lease and non-lease components, combining these components together and accounting for them as a single lease. Excluding ROU assets and lease liabilities relating to agreements between consolidated subsidiaries, adoption of the new standard resulted in the recognition of ROU assets of approximately $2.3 million , and current and non-current lease liabilities of approximately $0.6 million and $1.7 million , respectively, for operating leases as of January 1, 2019. Our accounting for finance leases remained substantially unchanged. The adoption of this guidance had no impact to our cash flows from operating, investing, or financing activities. For additional information see Note 13 – Leases . Accounting Pronouncements Not Yet Adopted ASU No. 2016-13, "Financial Instruments–Credit Losses (Topic 326)" In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments–Credit Losses (Topic 326). ASU 2016-13 amends current measurement techniques used to estimate credit losses for financial assets. The amendments in ASU 2016-13 are effective for financial statements issued for annual periods beginning after December 15, 2019, and interim periods within those annual periods. Early adoption is permitted. We are currently evaluating the impact of ASU 2016-13 but do not anticipate a material impact on our consolidated financial statements.

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
Acquisitions	Acquisition of Central Environmental Services In April 2019, BNN Eastern, LLC ("BNN Eastern"), a newly formed indirect subsidiary of TGE, entered into a Stock Purchase Agreement to acquire all of the outstanding stock of CES Holding Company, Inc., which owns all of the issued and outstanding membership interests of K & H Partners LLC, a company doing business as Central Environmental Services ("CES"). CES Holding Company, Inc. is a C corporation for U.S. federal income tax purposes and is considered a taxable entity for such purposes. CES owns and operates a salt water disposal facility located in the Utica and Marcellus area of Ohio. On May 1, 2019, the acquisition closed for cash consideration of approximately $52 million paid at closing, and the issuance of a 7.65% membership interest in BNN Eastern to one of the sellers in the transaction. In addition, the transaction includes a potential earn out payment to the sellers of approximately $3 million based on the achievement of certain milestones during 2019, which is payable in cash or in additional membership interests in BNN Eastern. The transaction qualifies as an acquisition of a business and is accounted for as a business combination under ASC 805. The following represents the fair value of assets acquired and liabilities assumed: Preliminary Adjustments Final (in thousands) Accounts receivable $ 1,391 $ — $ 1,391 Prepayments 67 — 67 Property, plant and equipment 6,900 4,400 11,300 Intangible asset 35,800 (2,900 ) 32,900 (1) Accounts payable and accrued liabilities (1,518 ) — (1,518 ) (2) Deferred tax liability (8,557 ) (189 ) (8,746 ) Net identifiable assets acquired 34,083 1,311 35,394 Goodwill 17,734 (1,311 ) 16,423 Net assets acquired (excluding cash) $ 51,817 $ — $ 51,817 (1) The $32.9 million intangible asset acquired represents customer relationships and is amortized on a straight-line basis over a period of 8 years. (2) Includes the estimated fair value of the liability for contingent consideration of $0.7 million . At June 30, 2019, the assets acquired and liabilities assumed in the acquisition were recorded at provisional amounts based on the preliminary purchase price allocation. During the three months ended September 30, 2019, the preliminary purchase price allocation was adjusted to reflect additional information obtained with respect to the property, plant and equipment acquired. The purchase price allocation was considered final as of September 30, 2019. The 7.65% equity interest in BNN Eastern held by noncontrolling interests was recorded at its acquisition date fair value of $3.4 million . The fair value of the noncontrolling interests were determined using a discounted cash flow analysis and adjusted for lack of control. These fair value measurements are based on significant inputs, such as forecasted cash flows and discount rates, that are not observable in the market and thus represent fair value measurements categorized within Level 3 of the fair value hierarchy under ASC 820. The goodwill recognized of $16.4 million is primarily attributed to synergies expected from combining the operations of TGE and CES. All the goodwill was assigned to our Gathering, Processing & Terminalling segment. Actual revenue and net income attributable to TGE from CES of $2.4 million and $0.8 million , respectively, was recognized in the accompanying condensed consolidated statements of income for the three months ended September 30, 2019 . Actual revenue and net income attributable to TGE from CES of $4.5 million and $0.9 million , respectively, was recognized in the accompanying condensed consolidated statements of income for the period from May 1, 2019 to September 30, 2019 . Pro Forma Financial Information Unaudited pro forma revenue and net income attributable to TGE for the three and nine months ended September 30, 2019 and 2018 is presented below as if the acquisition of CES had been completed on January 1, 2018. Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Revenue $ 226,709 $ 205,016 $ 640,377 $ 583,788 Net income attributable to TGE $ 72,524 $ 60,641 $ 195,565 $ 78,695 The pro forma financial information is not necessarily indicative of what the actual results of operations or financial position of TGE would have been if the transaction had in fact occurred on the date or for the period indicated, nor does it purport to project the results of operations or financial position of TGE for any future periods or as of any date. The pro forma financial information does not give effect to any cost savings, operating synergies, or revenue enhancements expected to result from the transaction or the costs to achieve these cost savings, operating synergies, and revenue enhancements. Joint Venture with Silver Creek In February 2018, we entered into an agreement with Silver Creek Midstream, LLC ("Silver Creek") to form Iron Horse Pipeline, LLC ("Iron Horse"), which owns the Iron Horse Pipeline. Effective January 1, 2019, the joint venture between us and Silver Creek was expanded through contributions to Powder River Gateway, a newly formed entity. We contributed our 75% membership interest in Iron Horse with a carrying value of $35.6 million , $37 million in cash, and various other assets, including terminal facilities under construction in Guernsey, Wyoming, valued at $86.9 million . Silver Creek contributed the PRE Pipeline and related terminal facilities in Guernsey, Wyoming, as well as their 25% membership interest in Iron Horse. Following the expansion of the joint venture, we own a 51% membership interest in Powder River Gateway and continue to operate the joint venture, while Silver Creek owns a 49% membership interest in Powder River Gateway. As Silver Creek retained certain participating rights with respect to Powder River Gateway, the 51% membership interest does not represent a controlling interest in Powder River Gateway. Accordingly, our investment in Powder River Gateway is accounted for under the equity method of accounting and reported as "Unconsolidated investments" on the condensed consolidated balance sheets. Consolidation of BNN Colorado Water At December 31, 2018, the assets acquired and liabilities assumed as a result of the consolidation of BNN Colorado Water, LLC ("BNN Colorado") were recorded at provisional amounts based on the preliminary purchase price allocation. No adjustments were made to these provisional amounts and the allocation of assets acquired and liabilities assumed in the acquisition was considered final as of June 30, 2019. Acquisition of NGL Water Solutions Bakken In November 2018, we acquired 100% of the membership interests in NGL Water Solutions Bakken, LLC ("NGL Water Solutions Bakken"), a produced water disposal system in the Bakken basin, for cash consideration of approximately $91.0 million , subject to working capital adjustments. NGL Water Solutions Bakken was subsequently merged into BNN North Dakota, LLC ("BNN North Dakota"). The transaction qualifies as an acquisition of a business and is accounted for as a business combination under ASC 805. The following represents the fair value of assets acquired and liabilities assumed: Preliminary Adjustments Final (in thousands) Accounts receivable $ 3,599 $ (3,599 ) $ — Prepayments and other current assets 5 — 5 Property, plant and equipment 17,200 — 17,200 Intangible asset 54,000 — 54,000 Accounts payable and accrued liabilities (949 ) 644 (305 ) Net identifiable assets acquired 73,855 (2,955 ) 70,900 Goodwill 17,145 2,955 20,100 Net assets acquired $ 91,000 $ — $ 91,000 At December 31, 2018, the assets acquired and liabilities assumed in the acquisition were recorded at provisional amounts based on the preliminary purchase price allocation. During the six months ended June 30, 2019, the preliminary purchase price allocation was adjusted for certain immaterial items related to working capital adjustments and the allocation of assets acquired and liabilities assumed in the acquisition was considered final as of June 30, 2019. Acquisition of Plaquemines Liquids Terminal, LLC In November 2018, we entered into a joint venture agreement with Drexel Hamilton Infrastructure Fund I, L.P. ("DHIF") to jointly own Plaquemines Liquids Terminal, LLC ("PLT"). PLT was formed with the intention of entering into agreements to develop a storage and terminalling facility. If developed, the facility is expected to be capable of offering up to 20 million barrels of storage for both crude oil and refined products and export facilities capable of loading Suezmax and Very Large Crude Carriers vessels for international delivery. In connection with our acquisition of a 100% preferred membership interest and a 80% common membership interest in PLT, we recognized liabilities related to DHIF's right to receive special distributions totaling $35 million , of which $25 million is included in "Other current liabilities" and the remaining $10 million is included in "Other long-term liabilities and deferred credits" in the condensed consolidated balance sheets. The special distributions are contingent upon PLT reaching certain milestones in the development and construction of the project facilities. Also in November 2018, PLT entered into an agreement with the Plaquemines Port & Harbor Terminal District to lease the land site on which PLT expects to construct the facilities.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	Totals of transactions with affiliated companies, excluding transactions disclosed elsewhere in these notes, are as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Processing and other revenues (1) $ 2,020 $ 1,838 $ 5,830 $ 5,603 Cost of transportation services (2) $ 210 $ — $ 730 $ — (1) Reflects the fee that NatGas receives as the operator of the Rockies Express Pipeline. (2) Reflects rent expense for crude oil storage and terminalling services provided by Powder River Gateway. Details of balances with affiliates included in "Accounts receivable, net" in the condensed consolidated balance sheets are as follows: September 30, 2019 December 31, 2018 (in thousands) Receivable from related parties: Rockies Express Pipeline LLC $ 2,900 $ 3,447 Powder River Gateway, LLC 379 — Pawnee Terminal, LLC 100 115 Iron Horse Pipeline, LLC — 186 Total receivable from related parties $ 3,379 $ 3,748 Details of gas imbalances with affiliated shippers included in "Prepayments and other current assets" and "Other current liabilities" in the condensed consolidated balance sheets are as follows: September 30, 2019 December 31, 2018 (in thousands) Affiliate gas imbalance receivables $ 30 $ 19 Affiliate gas imbalance payables $ 875 $ 742

Inventory

Inventory	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Inventory	The components of inventory at September 30, 2019 and December 31, 2018 consisted of the following: September 30, 2019 December 31, 2018 (in thousands) Crude oil $ 30,158 $ 23,205 Materials and supplies 7,747 8,206 Gas in underground storage 2,650 2,740 Natural gas liquids 473 165 Total inventory $ 41,028 $ 34,316

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	A summary of net property, plant and equipment by classification is as follows: September 30, 2019 December 31, 2018 (in thousands) Crude oil pipelines $ 1,365,353 $ 1,313,976 Gathering, processing and terminalling assets 970,749 889,168 Natural gas pipelines 624,489 607,343 General and other (1) 172,708 180,299 Construction work in progress 188,320 191,994 Accumulated depreciation and amortization (456,512 ) (380,351 ) Total property, plant and equipment, net $ 2,865,107 $ 2,802,429 (1) Includes approximately $30.7 million of land associated with the PLT capital lease as discussed in Note 13 – Leases .

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	9 Months Ended
	Sep. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure	Our investment in Rockies Express is recorded under the equity method of accounting and is reported as "Unconsolidated investments" on our condensed consolidated balance sheets. During the nine months ended September 30, 2019 , we recognized equity in earnings associated with our 75% membership interest in Rockies Express of $267.2 million , inclusive of the amortization of the negative basis difference, and received distributions from and made contributions to Rockies Express of $361.2 million and $49.9 million , respectively. Summarized financial information for Rockies Express is as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Revenue $ 233,010 $ 225,753 $ 696,094 $ 683,426 Operating income $ 130,908 $ 127,119 $ 397,629 $ 385,831 Net income to Members $ 100,968 $ 90,707 $ 322,212 $ 270,338 Rockies Express Senior Notes Offering On April 12, 2019, Rockies Express and U.S. Bank, National Association, as trustee, entered into an Indenture pursuant to which Rockies Express issued $550 million in aggregate principal amount of 4.95% senior notes due 2029. Substantially all of the net proceeds received by Rockies Express from the senior notes offering were used to repay Rockies Express' $525 million

Goodwill

Goodwill	9 Months Ended
	Sep. 30, 2019
Goodwill [Abstract]
Goodwill	Reconciliation of Goodwill The following table presents a reconciliation of the carrying amount of goodwill by reportable segment for the reporting period: Natural Gas Transportation Gathering, Processing & Terminalling Total (in thousands) Balance at December 31, 2018 $ 255,558 $ 166,425 $ 421,983 Goodwill acquired — 16,423 (1) 16,423 Other adjustments — 2,955 (2) 2,955 Balance at September 30, 2019 $ 255,558 $ 185,803 $ 441,361 (1) The $16.4 million of goodwill was recorded in connection with the acquisition of CES on May 1, 2019 as discussed further in Note 3 – Acquisitions . (2) The $3.0 million goodwill adjustment was recorded in connection with a purchase price allocation adjustment related to the NGL Water Solutions Bakken acquisition as discussed further in Note 3 – Acquisitions . Annual Goodwill Impairment Analysis We evaluate goodwill for impairment on an annual basis and whenever events or changes in circumstances necessitate an evaluation for impairment. Examples of such facts and circumstances include changes in the magnitude of the excess of fair value over carrying amount in the last valuation or changes in the business environment. Our annual impairment testing date is August 31. We evaluate goodwill for impairment at the reporting unit level, which is the same as, or one level below, an operating segment as defined in the segment reporting guidance of the Codification, using either the qualitative assessment option or proceeding directly to the quantitative impairment test depending on facts and circumstances of the reporting unit. For the purpose of goodwill impairment testing, goodwill was allocated to our reporting units according to the benefit received by the reporting unit at the date of acquisition. If we, after performing the qualitative assessment, determine it is "more likely than not" that the fair value of a reporting unit is greater than its carrying amount, then goodwill is not considered impaired. When goodwill is evaluated for impairment using the quantitative impairment test, the carrying amount of the reporting unit is compared to its fair value. If the fair value exceeds the carrying amount, goodwill is not considered impaired. If the carrying amount exceeds the reporting unit's fair value, then the reporting unit should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. We elected to apply the qualitative assessment option for one of our five reporting units during our 2019 annual goodwill impairment testing. In conducting the qualitative assessment we considered relevant factors and circumstances that affect the fair value or carrying amount of the reporting entity. Such factors included changes in discount rates, projected cash flows, macroeconomic considerations, industry and market considerations, overall financial performance, prior quantitative results, and entity and reporting unit specific events. For this reporting unit, the results of the qualitative assessment indicated that it was more likely than not that the fair value of the reporting units exceeds its book value. As such, we did not perform a quantitative impairment analysis, and we concluded that no impairment was indicated as of August 31, 2019. For the remaining four reporting units, we did not elect to apply the qualitative assessment option and instead we proceeded directly to the quantitative impairment test. We compared the fair value of the reporting units with their respective book values, including goodwill, by using an income approach based on a discounted cash flow analysis. The fair value of the reporting units was determined on a stand-alone basis from the perspective of a market participant and included a sensitivity analysis of the impact of changes in various assumptions. This approach required us to make long-term forecasts of future operating results and various other assumptions and estimates, the most significant of which are gross margin, operating expenses, general and administrative expenses, long-term growth rates, maintenance capital expenditures, and the weighted average cost of capital. The fair value of the reporting units was determined using significant unobservable inputs, considered Level 3 under the fair value hierarchy in the Codification. For these reporting units, the results of the quantitative impairment test indicated no impairment as the fair value of each reporting unit was greater than its respective book value. As a result, in accordance with the Codification guidance, we did not record a goodwill impairment during the nine months ended September 30, 2019. Unpredictable events or deteriorating market or operating conditions could result in a future change to the discounted cash flow models and cause impairments in the future. We continue to monitor potential impairment indicators to determine if a triggering event occurs and will perform additional goodwill impairment analyses as necessary. Approximately $79.2 million of goodwill is allocated to the Midstream Facilities reporting unit, which is a component of our Gathering, Processing & Terminalling segment. As a result of current market conditions, certain producers from which the Midstream Facilities reporting unit receives natural gas for processing have recently indicated that they currently expect to deliver lower volumes than previously anticipated. The results of the Midstream Facilities reporting unit's impairment testing as of August 31, 2019 indicate that the fair value of the reporting unit exceeds the carrying value by approximately 17% . As a result, no impairment charge was recorded, however our analysis includes assumptions of a gradual recovery of commodity prices and a corresponding increase in volumes over time. If our outlook is not realized, or our producers further decrease volumes, we may recognize an impairment in the future.

Risk Management

Risk Management	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management	Stanchion engages in the business of trading energy related products and services, which exposes us to market variables and commodity price risk. We may enter into physical contracts or financial instruments with the objective of realizing a positive margin from the purchase and sale of these commodity-based instruments. We have a comprehensive risk management policy for Stanchion adopted by the board of directors of our general partner and a Risk Management Committee responsible for the overall management of credit risk and commodity risk at Stanchion, including establishing and monitoring exposure limits. We also occasionally enter into derivative contracts with third parties for the purpose of hedging exposures that accompany our normal business activities. Our normal business activities directly and indirectly expose us to risks associated with changes in the market price of crude oil and natural gas, among other commodities. For example, the risks associated with changes in the market price of crude oil and natural gas include, among others (i) pre-existing or anticipated physical crude oil and natural gas sales, (ii) natural gas purchases and (iii) natural gas system use and storage. We have elected not to apply hedge accounting and changes in the fair value of all derivative contracts are recorded in earnings in the period in which the change occurs. Fair Value of Derivative Contracts The following table summarizes the fair values of our derivative contracts included in the condensed consolidated balance sheets: Balance Sheet Location September 30, 2019 December 31, 2018 (in thousands) Crude oil derivative contracts Prepayments and other current assets $ 4,015 $ 3,526 Crude oil derivative contracts Other current liabilities $ 454 $ 1,642 As of September 30, 2019 , the amounts shown represent the fair value of crude oil derivative contracts for the forward purchase of 2,157,325 and the forward sale of 4,349,000 barrels of crude oil consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020. As of December 31, 2018 , the amounts shown represent the fair value of crude oil derivative contracts for the forward purchase of 2,105,146 and the forward sale of 1,274,500 barrels of crude oil consisting of fixed price and floating price contracts, which will settle throughout 2019. Effect of Derivative Contracts in the Statements of Income The following table summarizes the impact of derivative contracts not designated as hedging contracts for the three and nine months ended September 30, 2019 and 2018 : Location of gain recognized Amount of gain recognized in income on derivatives Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Crude oil derivative contracts Sales of natural gas, NGLs, and crude oil $ 14,574 $ 9,435 $ 40,631 $ 16,665 Credit Risk We have counterparty credit risk as a result of our use of derivative contracts. Counterparties to our commodity derivatives consist of market participants and major financial institutions. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions. Our derivative contracts are entered into with counterparties through central trading organizations such as futures, options or stock exchanges or counterparties outside of central trading organizations. While we typically enter into derivative transactions with investment grade counterparties and actively monitor their credit ratings, it is nevertheless possible that from time to time losses will result from counterparty credit risk in the future. The maximum potential exposure to credit losses on our crude oil derivative contracts at September 30, 2019 was: Asset Position (in thousands) Gross $ 4,015 Netting agreement impact — Cash collateral held — Net exposure $ 4,015 As of September 30, 2019 , we had $0.5 million of cash in margin accounts in support of our commodity derivative contracts. As of December 31, 2018 , we did not have any cash in margin accounts in support of our commodity derivative contracts. Fair Value Derivative assets and liabilities are measured and reported at fair value. Derivative contracts can be exchange-traded or over-the-counter ("OTC"). OTC commodity derivatives are valued using models utilizing a variety of inputs including contractual terms and commodity and interest rate curves. The selection of a particular model and particular inputs to value an OTC derivative contract depends upon the contractual terms of the instrument as well as the availability of pricing information in the market. We use similar models to value similar instruments. For OTC derivative contracts that trade in liquid markets, such as generic forwards and swaps, model inputs can generally be verified and model selection does not involve significant management judgment. Such contracts are typically classified within Level 2 of the fair value hierarchy. The following table summarizes the fair value measurements of our derivative contracts as of September 30, 2019 and December 31, 2018 , based on the fair value hierarchy: Asset Fair Value Measurements Using Total Quoted prices in Significant Significant (in thousands) As of September 30, 2019: Crude oil derivative contracts $ 4,015 $ — $ 4,015 $ — As of December 31, 2018: Crude oil derivative contracts $ 3,526 $ — $ 3,526 $ — Liability Fair Value Measurements Using Total Quoted prices in Significant Significant (in thousands) As of September 30, 2019: Crude oil derivative contracts $ 454 $ — $ 454 $ — As of December 31, 2018: Crude oil derivative contracts $ 1,642 $ — $ 1,642 $ —

Long-term Debt

Long-term Debt	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Long-term Debt	Our long-term debt is held at TEP and consisted of the following at September 30, 2019 and December 31, 2018 : September 30, 2019 December 31, 2018 (in thousands) Revolving credit facility $ 1,467,000 $ 1,224,000 4.75% senior notes due October 1, 2023 500,000 500,000 5.50% senior notes due September 15, 2024 750,000 750,000 5.50% senior notes due January 15, 2028 750,000 750,000 Less: Deferred financing costs, net (1) (18,848 ) (21,421 ) Plus: Unamortized premium on 2028 Notes 3,116 3,379 Total long-term debt, net $ 3,451,268 $ 3,205,958 (1) Deferred financing costs, net as presented above relate solely to the Senior Notes (as defined below). Deferred financing costs associated with our revolving credit facility are presented in noncurrent assets on our condensed consolidated balance sheets. Senior Unsecured Notes On February 27, 2019, TEP and Tallgrass Energy Finance Corp. (together, the "Issuers"), together with the TEP subsidiary guarantors party thereto (the "Guarantors") and U.S. Bank National Association, as trustee (the "Trustee"), entered into supplemental indentures (the "Supplemental Indentures") to amend certain provisions of each of (i) the Indenture governing the 4.75% senior notes due 2023 (the "2023 Notes"), dated as of September 26, 2018, among the Issuers, the Guarantors and Trustee, (ii) the Indenture governing the 5.50% senior notes due 2024 (the "2024 Notes"), dated as of September 1, 2016, among the Issuers, the Guarantors and the Trustee, and (iii) the Indenture governing the 5.50% senior notes due 2028 (the "2028 Notes"), dated as of September 15, 2017, among the Issuers, the Guarantors and the Trustee (collectively, the "Indentures"). The Supplemental Indentures (a) amended the defined term "Change of Control" in each Indenture to provide that the Blackstone Acquisition did not constitute a Change of Control under such Indenture, (b) changed the definition of "Qualifying Owners" in the applicable Indenture to provide that Blackstone Infrastructure Partners L.P., Vencap Holdings (1992) Pte. Ltd. and their respective affiliates, funds, holding companies and investment vehicles, among others, are Qualifying Owners under such Indenture, and (c) added to, amended, supplemented or changed certain other defined terms contained in each Indenture related to the foregoing. The 2023 Notes, 2024 Notes, and 2028 Notes are together referred to as the "Senior Notes." As of September 30, 2019 , TEP was in compliance with the covenants required under the Indentures. Revolving Credit Facility The following table sets forth the available borrowing capacity under our revolving credit facility as of September 30, 2019 and December 31, 2018 : September 30, 2019 December 31, 2018 (in thousands) Total capacity under the revolving credit facility $ 2,250,000 $ 2,250,000 Less: Outstanding borrowings under the revolving credit facility (1,467,000 ) (1,224,000 ) Less: Letters of credit issued under the revolving credit facility (94 ) (94 ) Available capacity under the revolving credit facility $ 782,906 $ 1,025,906 On February 22, 2019, TEP and certain of its subsidiaries entered into a Consent and Amendment No. 2 to the Second Amended and Restated Credit Agreement (the "Consent and Amendment") with Wells Fargo Bank, National Association, as administrative agent, and the required lenders party thereto. The Consent and Amendment modified that certain Second Amended and Restated Credit Agreement dated as of June 2, 2017, as previously amended by that certain Amendment No. 1 to Second Amended and Restated Credit Agreement dated as of July 26, 2018 (as amended, the "Credit Agreement"). The Credit Agreement governs our revolving credit facility. In the Consent and Amendment, the required lenders under the Credit Agreement (i) consented to the Blackstone Acquisition pursuant to the terms and conditions of the Purchase Agreement, (ii) agreed that no Default (as defined in the Credit Agreement) under the Credit Agreement, if any, that may have resulted from a Change in Control (as defined in the Credit Agreement) caused by the consummation of the Blackstone Acquisition pursuant to the terms and conditions set forth in the Purchase Agreement will be deemed to have occurred, and (iii) agreed to modify the definition of "Permitted Holders" in Section 1.01 of the Credit Agreement (which is used in the definition of Change in Control) to reflect the change in ownership as a result of the Blackstone Acquisition. As of September 30, 2019 , TEP was in compliance with the covenants required under its revolving credit facility. As of September 30, 2019 , the weighted average interest rate on outstanding borrowings under the revolving credit facility was 3.54% . During the nine months ended September 30, 2019 , the weighted average effective interest rate under the revolving credit facility, including the interest on outstanding borrowings under the revolving credit facility, commitment fees, and amortization of deferred financing costs, was 4.35% . Fair Value The following table sets forth the carrying amount and fair value of long-term debt, which is not measured at fair value in the condensed consolidated balance sheets as of September 30, 2019 and December 31, 2018 , but for which fair value is disclosed: Fair Value Quoted prices Significant Significant Total Carrying (in thousands) As of September 30, 2019: Revolving credit facility $ — $ 1,467,000 $ — $ 1,467,000 $ 1,467,000 2023 Notes $ — $ 502,135 $ — $ 502,135 $ 495,466 2024 Notes $ — $ 748,305 $ — $ 748,305 $ 742,344 2028 Notes $ — $ 735,998 $ — $ 735,998 $ 746,458 As of December 31, 2018: Revolving credit facility $ — $ 1,224,000 $ — $ 1,224,000 $ 1,224,000 2023 Notes $ — $ 485,285 $ — $ 485,285 $ 494,603 2024 Notes $ — $ 737,745 $ — $ 737,745 $ 741,196 2028 Notes $ — $ 726,503 $ — $ 726,503 $ 746,159 The long-term debt borrowed under the revolving credit facility is carried at amortized cost. As of September 30, 2019 and December 31, 2018 , the fair value of borrowings under the revolving credit facility approximates the carrying amount of the borrowings using a discounted cash flow analysis. The Senior Notes are carried at amortized cost, net of deferred financing costs. The estimated fair value of the Senior Notes is based upon quoted market prices adjusted for illiquid markets. We are not aware of any factors that would significantly affect the estimated fair value subsequent to September 30, 2019 .

Partnership Equity

Partnership Equity	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Partnership Equity	TGE Dividends to Holders of Class A Shares The following table details the dividends for the periods indicated: Three Months Ended Date Paid Dividends to Class A Shareholders Dividends per Class A Share (in thousands, except per share amounts) September 30, 2019 November 14, 2019 (1) $ 98,559 $ 0.5500 June 30, 2019 August 14, 2019 96,767 0.5400 March 31, 2019 May 15, 2019 94,975 0.5300 December 31, 2018 February 14, 2019 81,304 0.5200 September 30, 2018 November 14, 2018 79,717 0.5100 June 30, 2018 August 14, 2018 77,052 0.4975 March 31, 2018 May 15, 2018 28,316 0.4875 (1) The dividend announced on October 10, 2019 for the third quarter of 2019 will be paid on November 14, 2019 to Class A shareholders of record at the close of business on October 31, 2019 . Exchange Rights Our current Class B shareholders (collectively, the "Exchange Right Holders") own an equal number of Tallgrass Equity units. The Exchange Right Holders, and any permitted transferees of their Tallgrass Equity units, each have the right to exchange all or a portion of their Tallgrass Equity units for Class A shares at an exchange ratio of one Class A share for each Tallgrass Equity unit exchanged, which we refer to as the Exchange Right. The Exchange Right may be exercised only if, simultaneously therewith, an equal number of our Class B shares are transferred by the exercising party to us. Upon such exchange, we will cancel the Class B shares received from the exercising party. During the nine months ended September 30, 2019 , 21,751,018 Class A shares were issued and an equal number of Class B shares were cancelled as a result of the exercise of the Exchange Right. Following the Blackstone Acquisition that closed on March 11, 2019 discussed in Note 1 – Description of Business , the Exchange Rights Holders consist of certain of the Sponsor Entities and certain members of our management. Noncontrolling Interests As of September 30, 2019 , noncontrolling interests in our subsidiaries consisted of a 36.30% interest in Tallgrass Equity held by the Exchange Right Holders, as well as noncontrolling interests in certain subsidiaries held by unaffiliated third parties, including an approximate 40% membership interest in Deeprock Development, LLC ("Deeprock Development"), an approximate 25% membership interest in BNN West Texas, LLC ("BNN West Texas"), a 37% membership interest in BNN Colorado, a 20% common membership interest in PLT, and an approximate 8% membership interest in BNN Eastern. During the nine months ended September 30, 2019 , we recognized contributions from and distributions to noncontrolling interests of $2.3 million and $178.9 million , respectively. Distributions to noncontrolling interests consisted of Tallgrass Equity distributions to the Exchange Right Holders of $173.7 million and distributions to Deeprock Development, BNN West Texas, and BNN Colorado noncontrolling interests of $5.2 million in the aggregate. During the nine months ended September 30, 2018 , we recognized contributions from and made distributions to noncontrolling interests of $0.2 million and $262.9 million , respectively. Distributions to noncontrolling interests consisted of Tallgrass Equity distributions to the Exchange Right Holders of $160.6 million , distributions to TEP unitholders of $97.7 million , and distributions to Deeprock Development and Pony Express noncontrolling interests of $4.6 million in the aggregate. Other Contributions and Distributions During the nine months ended September 30, 2018 , TGE recognized the following other contributions and distributions: • TGE was deemed to have made a noncash capital distribution of $198.0 million , which represents the excess purchase price over the $53.8 million carrying value of the 5,619,218 TEP common units acquired as of February 7, 2018; • TGE was deemed to have received a noncash capital contribution of $108.5 million , which represents the excess carrying value of the 25.01% membership interest in Rockies Express acquired as of February 7, 2018 over the fair value of the consideration paid; and • TEP was deemed to have made a noncash capital distribution of $16.2 million , which represents the excess purchase price over the $33.8 million carrying value of the additional 2% membership interest in Pony Express acquired as of February 1, 2018. Share-Based Compensation The Blackstone Acquisition discussed in Note 1 – Description of Business constituted a change in control event under certain Equity Participation Share agreements outstanding under the LTIP plan, resulting in the accelerated vesting of 1,092,637 Class A shares (net of tax withholding of approximately 543,909 Class A shares) with a weighted average grant date fair value of $18.82 . These Class A shares were issued in April 2019. The accelerated vesting resulted in the recognition of equity-based compensation costs of $12.5 million in "General and administrative" costs in the condensed consolidated statements of income during the nine months ended September 30, 2019 . In addition, 1,796,400 Equity Participation Shares with a weighted average grant date fair value of $15.19 were granted during the nine months ended September 30, 2019 .

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customers	Disaggregated Revenue A summary of our revenue by line of business is as follows: Three Months Ended September 30, 2019 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 111,572 $ — $ — $ 111,572 Natural gas transportation - firm service 30,066 — — (490 ) 29,576 Water business services — — 31,311 — 31,311 Natural gas gathering & processing fees — — 7,021 — 7,021 All other (1) 2,742 15,215 5,425 (18,836 ) 4,546 Total service revenue 32,808 126,787 43,757 (19,326 ) 184,026 Natural gas liquids sales — — 16,256 — 16,256 Natural gas sales — — 8,932 — 8,932 Crude oil sales — — 138 — 138 Total commodity sales revenue — — 25,326 — 25,326 Total revenue from contracts with customers 32,808 126,787 69,083 (19,326 ) 209,352 Other revenue (2) — — 21,760 (4,403 ) 17,357 Total revenue (3) $ 32,808 $ 126,787 $ 90,843 $ (23,729 ) $ 226,709 Nine Months Ended September 30, 2019 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 306,288 $ — $ — $ 306,288 Natural gas transportation - firm service 94,571 — — (1,374 ) 93,197 Water business services — — 80,896 — 80,896 Natural gas gathering & processing fees — — 18,431 — 18,431 All other (1) 8,831 45,723 12,689 (54,584 ) 12,659 Total service revenue 103,402 352,011 112,016 (55,958 ) 511,471 Natural gas liquids sales — — 46,303 — 46,303 Natural gas sales 119 — 24,441 — 24,560 Crude oil sales — 4,730 384 — 5,114 Total commodity sales revenue 119 4,730 71,128 — 75,977 Total revenue from contracts with customers 103,521 356,741 183,144 (55,958 ) 587,448 Other revenue (2) — — 62,495 (14,358 ) 48,137 Total revenue (3) $ 103,521 $ 356,741 $ 245,639 $ (70,316 ) $ 635,585 Three Months Ended September 30, 2018 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 100,614 $ — $ — $ 100,614 Natural gas transportation - firm service 31,070 — — (793 ) 30,277 Water business services — — 12,837 — 12,837 Natural gas gathering & processing fees — — 6,631 — 6,631 All other (1) 2,551 13,321 6,709 (17,636 ) 4,945 Total service revenue 33,621 113,935 26,177 (18,429 ) 155,304 Natural gas liquids sales — — 26,201 — 26,201 Natural gas sales 456 — 5,517 — 5,973 Crude oil sales — 2,315 147 — 2,462 Total commodity sales revenue 456 2,315 31,865 — 34,636 Total revenue from contracts with customers 34,077 116,250 58,042 (18,429 ) 189,940 Other revenue (2) — — 13,570 (3,190 ) 10,380 Total revenue (3) $ 34,077 $ 116,250 $ 71,612 $ (21,619 ) $ 200,320 Nine Months Ended September 30, 2018 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 286,594 $ — $ — $ 286,594 Natural gas transportation - firm service 96,166 — — (4,074 ) 92,092 Water business services — — 38,246 — 38,246 Natural gas gathering & processing fees — — 17,429 — 17,429 All other (1) 8,240 26,124 18,809 (36,832 ) 16,341 Total service revenue 104,406 312,718 74,484 (40,906 ) 450,702 Natural gas liquids sales — — 77,287 — 77,287 Natural gas sales 802 — 17,907 — 18,709 Crude oil sales — 6,290 515 — 6,805 Total commodity sales revenue 802 6,290 95,709 — 102,801 Total revenue from contracts with customers 105,208 319,008 170,193 (40,906 ) 553,503 Other revenue (2) — — 28,869 (9,369 ) 19,500 Total revenue (3) $ 105,208 $ 319,008 $ 199,062 $ (50,275 ) $ 573,003 (1) Includes revenue from crude oil terminal services, interruptible natural gas transportation and storage, and natural gas park and loan service. (2) Includes lease and derivative revenue not subject to ASC 606. (3) Excludes revenue recognized at unconsolidated investments, including revenue recognized at Rockies Express of $233.0 million and $696.1 million for the three and nine months ended September 30, 2019 , respectively, and $225.8 million and $683.4 million for the three and nine months ended September 30, 2018 , respectively. See Note 7 – Investments in Unconsolidated Affiliates for additional information about our investment in Rockies Express. Performance Obligations On September 30, 2019 , we had $1.4 billion of remaining performance obligations at our consolidated subsidiaries, which we refer to as total backlog. Total backlog includes performance obligations under long-term crude oil transportation contracts with committed shippers, natural gas firm transportation and firm storage contracts, and certain water business service contracts with minimum volume commitments, and excludes variable consideration that is not estimated at contract inception, as discussed further below. We expect to recognize the total backlog during the remainder of 2019 and future periods as follows (in thousands): Year Estimated Revenue 2019 – remaining $ 126,248 2020 407,639 2021 219,345 2022 213,821 2023 176,480 Thereafter 259,331 Total $ 1,402,864 Contract Estimates Accounting for long-term contracts involves the use of various techniques to estimate total contract revenue. Contract estimates are based on various assumptions to project the outcome of future events that often span several years. These assumptions include the anticipated volumes of crude oil expected to be delivered by our customers for transport in future periods. The nature of our contracts gives rise to several types of variable consideration, including PLA, volumetric charges for actual volumes delivered, overrun charges, and other fees that are contingent on the actual volumes delivered by our customers. As the amount of variable consideration is allocable to each distinct performance obligation within the series of performance obligations that comprise the single performance obligation and the uncertainty related to the consideration is resolved each month as the distinct service is provided, we do not estimate the total variable consideration for the single overall performance obligation. Consequently, we are able to include in the transaction price each month the actual amount of variable consideration because no uncertainty exists surrounding the services provided that month. Certain of our contracts include provisions in which a portion of the consideration is noncash. In our Crude Oil Transportation segment, we collect PLA from our customers. As crude oil is transported, we earn, and take title to, a portion of the oil transported for our services. Any PLA that remains after replacing losses in transit can be sold. Where PLA is determined to be a component of compensation for the transportation services provided, crude oil retained is recognized in revenue at its contract inception fair value. In our Gathering, Processing & Terminalling segment, we retain commodity products as consideration under certain of our gathering and processing arrangements. Processing fee revenue is recorded when the performance obligation is completed based on the value of the product received at the time services are performed. At this time, the variability of the non-cash consideration related to both form (price) and other-than-form (volume and product mix), which are interrelated, is resolved. As a significant change in one or more of these estimates could affect the amount and timing of revenue recognized under our customer contracts, we review and update our contract-related estimates regularly. Contract Balances The timing of revenue recognition, billings, and cash collections may result in billed accounts receivable, unbilled receivables (contract assets), and deferred revenue (contract liabilities) on our condensed consolidated balance sheets. Revenue is generally billed and collected monthly based on services provided or commodity volumes sold. In our Crude Oil Transportation segment, we recognize shipper deficiencies, or deferred revenue, for barrels committed by the customer to be transported in a month but not physically received by us for transport or delivered to the customers' agreed upon destination point. These shipper deficiencies are charged at the committed tariff rate per barrel and recorded as a contract liability until the barrels are physically transported and delivered, or when the likelihood that the customer will utilize the deficiency balance becomes remote. We also recognize contract liabilities, in the form of deferred revenue, in the Gathering, Processing & Terminalling segment under certain water business services contracts subject to minimum volume commitments. We receive deficiency payments for volumes committed by the customer in a month but not physically delivered to the customer or received by us for disposal. These deficiencies are charged at the contracted rate per barrel and recorded as a contract liability until the barrels are received from the customer for disposal, or when the likelihood that the customer will utilize the deficiency balance becomes remote. Contract balances at September 30, 2019 and December 31, 2018 were as follows: September 30, 2019 December 31, 2018 (in thousands) Accounts receivable from contracts with customers $ 83,712 $ 80,935 Other accounts receivable (1) 159,202 151,414 Receivable from related parties 3,379 3,748 Accounts receivable, net $ 246,293 $ 236,097 Deferred revenue from contracts with customers (2) $ 125,198 $ 111,095 (1) Other accounts receivable primarily consists of receivables under crude oil forward purchase and sale arrangements that are accounted for as derivatives under ASC 815. (2) Revenue recognized during the three and nine months ended September 30, 2019 that was included in the deferred revenue balance at the beginning of the period was $10.5 million and $17.0 million , respectively. This revenue primarily represented the utilization of shipper deficiencies at Pony Express.

Leases

Leases	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Leases of Lessee Disclosure [Text Block]	We account for leases in accordance with ASC Topic 842, Leases, which we adopted on January 1, 2019, applying the modified retrospective transition approach as of the effective date of adoption. See Note 2 – Summary of Significant Accounting Policies for additional information regarding the impacts of adoption. We enter into operating leases as lessee for certain office space and equipment. We also have a capital lease agreement to lease the land site on which PLT expects to construct storage and terminalling facilities. In November 2018, we entered into a joint venture agreement with DHIF to jointly own PLT, an entity formed with the intention of developing a storage and terminalling facility. At the same time, PLT entered into an agreement with the Plaquemines Port & Harbor Terminal District to lease the land site on which PLT expects to construct the facilities. Under ASC 842, a contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. We assess whether an arrangement is or contains a lease at inception of the contract. For all leases (finance and operating leases), other than those that qualify for the short-term recognition exemption, we recognize as of the lease commencement date on the balance sheet a liability for our obligation related to the lease and a corresponding asset representing our right to use the underlying asset over the period of use. The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As most of our leases do not provide an implicit rate, we determine the appropriate discount rate using our incremental secured borrowing rate, with consideration given to the nature and term of the leased asset. Our leases have remaining terms of up to approximately 39 years . Certain of our lease agreements contain options to extend or early terminate the agreement. The lease term used to calculate the lease asset and liability at commencement includes options to extend or terminate the lease when it is reasonably certain that we will exercise that option. When determining whether it is reasonably certain that we will exercise an option at commencement, we consider various economic factors, including operating strategies, the nature, length, and underlying terms of the agreement, as well as the uncertainty of the condition of leased equipment at the end of the lease term. Based on these determinations, we generally determine that the exercise of renewal options would not be reasonably certain in determining the expected lease term. For the three and nine months ended September 30, 2019 , operating lease cost was $0.5 million and $1.0 million , respectively. For the nine months ended September 30, 2019 , cash paid included in operating cash flows was $0.9 million . During these periods the existing finance lease did not have any lease payments or variable lease cost. Supplemental information related to our existing leases as of September 30, 2019 was as follows: Balance Sheet Location September 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,673 (1) Current operating lease liabilities Other current liabilities $ 1,239 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,496 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 15.6 years Finance leases 39.2 years Weighted Average Discount Rate: Operating leases 5.88 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.0 million and current and non-current lease liabilities of $0.1 million and $8.9 million , respectively, related to Guernsey Terminal capacity that we lease from Powder River Gateway. (2) PLT satisfied the initial capital lease obligation of $30.7 million at lease inception and as a result has no outstanding liability or imputed interest on the future minimum rental commitments. Maturities of lease liabilities as of September 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 481 $ 449 2020 1,913 449 2021 1,315 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 18,961 20,015 Less: discounting for present value and other adjustments (7,226 ) (20,015 ) Present value of lease liabilities $ 11,735 $ — (1) Future lease payments for finance leases consist of the annual payments under the PLT land site lease. At lease inception, the present value of the future lease payments exceeded the fair value of the leased property. As a result, the right of use asset and capital lease obligation were recorded at the $30.7 million fair value of land. On that date, PLT made a payment of $30.7 million , immediately relieving the capital lease obligation. As a result, PLT does not have an outstanding capital lease obligation or impute interest on the future minimum rental commitments and will recognize expense for the future lease payments in the period in which they are made. Under various lease agreements, Tallgrass Midstream, LLC ("TMID"), as lessor, leases capacity on NGL pipelines that were constructed for third parties, and Deeprock Development, as lessor, leases capacity at certain of its storage facilities. Rental income for these arrangements was approximately $2.6 million and $7.3 million for the three and nine months ended September 30, 2019 , respectively, and was recorded as "Processing and other revenues" in the condensed consolidated statements of income. Under a lease agreement initially effective November 13, 2012, Tallgrass Interstate Gas Transmission, LLC ("TIGT"), as lessor, leases a portion of its office space to a third party. Rental income was approximately $0.1 million and $0.5 million for the three and nine months ended September 30, 2019 , respectively, and was recorded as "Other income, net" in the condensed consolidated statements of income. At September 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 2,374 2020 5,613 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 26,659 Information as of December 31, 2018 under historical lease accounting guidance: At December 31, 2018 , our future minimum rental commitments under major, non-cancelable leases were as follows: Year Operating Leases Capital Lease (in thousands) 2019 $ 1,074 $ 449 2020 922 449 2021 483 449 2022 240 449 2023 147 449 Thereafter 364 17,770 Total $ 3,230 $ 20,015
Lessor, Operating Leases [Text Block]	We account for leases in accordance with ASC Topic 842, Leases, which we adopted on January 1, 2019, applying the modified retrospective transition approach as of the effective date of adoption. See Note 2 – Summary of Significant Accounting Policies for additional information regarding the impacts of adoption. We enter into operating leases as lessee for certain office space and equipment. We also have a capital lease agreement to lease the land site on which PLT expects to construct storage and terminalling facilities. In November 2018, we entered into a joint venture agreement with DHIF to jointly own PLT, an entity formed with the intention of developing a storage and terminalling facility. At the same time, PLT entered into an agreement with the Plaquemines Port & Harbor Terminal District to lease the land site on which PLT expects to construct the facilities. Under ASC 842, a contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. We assess whether an arrangement is or contains a lease at inception of the contract. For all leases (finance and operating leases), other than those that qualify for the short-term recognition exemption, we recognize as of the lease commencement date on the balance sheet a liability for our obligation related to the lease and a corresponding asset representing our right to use the underlying asset over the period of use. The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As most of our leases do not provide an implicit rate, we determine the appropriate discount rate using our incremental secured borrowing rate, with consideration given to the nature and term of the leased asset. Our leases have remaining terms of up to approximately 39 years . Certain of our lease agreements contain options to extend or early terminate the agreement. The lease term used to calculate the lease asset and liability at commencement includes options to extend or terminate the lease when it is reasonably certain that we will exercise that option. When determining whether it is reasonably certain that we will exercise an option at commencement, we consider various economic factors, including operating strategies, the nature, length, and underlying terms of the agreement, as well as the uncertainty of the condition of leased equipment at the end of the lease term. Based on these determinations, we generally determine that the exercise of renewal options would not be reasonably certain in determining the expected lease term. For the three and nine months ended September 30, 2019 , operating lease cost was $0.5 million and $1.0 million , respectively. For the nine months ended September 30, 2019 , cash paid included in operating cash flows was $0.9 million . During these periods the existing finance lease did not have any lease payments or variable lease cost. Supplemental information related to our existing leases as of September 30, 2019 was as follows: Balance Sheet Location September 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,673 (1) Current operating lease liabilities Other current liabilities $ 1,239 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,496 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 15.6 years Finance leases 39.2 years Weighted Average Discount Rate: Operating leases 5.88 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.0 million and current and non-current lease liabilities of $0.1 million and $8.9 million , respectively, related to Guernsey Terminal capacity that we lease from Powder River Gateway. (2) PLT satisfied the initial capital lease obligation of $30.7 million at lease inception and as a result has no outstanding liability or imputed interest on the future minimum rental commitments. Maturities of lease liabilities as of September 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 481 $ 449 2020 1,913 449 2021 1,315 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 18,961 20,015 Less: discounting for present value and other adjustments (7,226 ) (20,015 ) Present value of lease liabilities $ 11,735 $ — (1) Future lease payments for finance leases consist of the annual payments under the PLT land site lease. At lease inception, the present value of the future lease payments exceeded the fair value of the leased property. As a result, the right of use asset and capital lease obligation were recorded at the $30.7 million fair value of land. On that date, PLT made a payment of $30.7 million , immediately relieving the capital lease obligation. As a result, PLT does not have an outstanding capital lease obligation or impute interest on the future minimum rental commitments and will recognize expense for the future lease payments in the period in which they are made. Under various lease agreements, Tallgrass Midstream, LLC ("TMID"), as lessor, leases capacity on NGL pipelines that were constructed for third parties, and Deeprock Development, as lessor, leases capacity at certain of its storage facilities. Rental income for these arrangements was approximately $2.6 million and $7.3 million for the three and nine months ended September 30, 2019 , respectively, and was recorded as "Processing and other revenues" in the condensed consolidated statements of income. Under a lease agreement initially effective November 13, 2012, Tallgrass Interstate Gas Transmission, LLC ("TIGT"), as lessor, leases a portion of its office space to a third party. Rental income was approximately $0.1 million and $0.5 million for the three and nine months ended September 30, 2019 , respectively, and was recorded as "Other income, net" in the condensed consolidated statements of income. At September 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 2,374 2020 5,613 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 26,659 Information as of December 31, 2018 under historical lease accounting guidance: At December 31, 2018 , our future minimum rental commitments under major, non-cancelable leases were as follows: Year Operating Leases Capital Lease (in thousands) 2019 $ 1,074 $ 449 2020 922 449 2021 483 449 2022 240 449 2023 147 449 Thereafter 364 17,770 Total $ 3,230 $ 20,015

Net Income per Class A Share

Net Income per Class A Share	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Net Income per Class A Share	Basic net income per Class A share is determined by dividing net income attributable to TGE by the weighted average number of outstanding Class A shares during the period. Class B shares do not share in the earnings of TGE. Accordingly, basic and diluted net income per Class B share has not been presented. Diluted net income per Class A share is determined by dividing net income attributable to TGE by the weighted average number of outstanding diluted Class A shares during the period. For purposes of calculating diluted net income per Class A share, we considered the impact of possible future exercises of the Exchange Right by the Exchange Right Holders on both net income attributable to TGE and the diluted weighted average number of Class A shares outstanding. The Exchange Right Holders refers to the group of persons who collectively own all of TGE's outstanding Class B shares and an equivalent number of Tallgrass Equity units. The Exchange Right Holders are entitled to exercise the right to exchange their Tallgrass Equity units (together with an equivalent number of TGE Class B shares) for TGE Class A shares at an exchange ratio of one TGE Class A share for each Tallgrass Equity unit exchanged, which we refer to as the Exchange Right. As of September 30, 2019 , the Exchange Right Holders primarily consist of certain of the Sponsor Entities and certain members of our management. Pursuant to the TGE partnership agreement and the Tallgrass Equity limited liability company agreement, our capital structure and the capital structure of Tallgrass Equity will generally replicate one another in order to maintain the one-for-one exchange ratio between the Tallgrass Equity units and Class B shares, on the one hand, and our Class A shares, on the other hand. As a result, the exchange of any Class B shares for Class A shares does not have a dilutive effect on basic net income per Class A share. However, for the three and nine months ended September 30, 2019 and 2018 , the assumed issuance of TGE Equity Participation Shares would have had a dilutive effect on basic net income per Class A share as shown in the table below. The following table illustrates the calculation of net income per Class A share for the three and nine months ended September 30, 2019 and 2018 : Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands, except per unit amounts) Basic Net Income per Class A Share Net income attributable to TGE $ 72,524 $ 59,550 $ 194,730 $ 77,348 Basic weighted average Class A Shares outstanding 179,197 155,001 173,322 91,183 Basic net income per Class A share $ 0.40 $ 0.38 $ 1.12 $ 0.85 Diluted Net Income per Class A Share Net income attributable to TGE $ 72,524 $ 59,550 $ 194,730 $ 77,348 Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares 264 304 801 1,097 Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares $ 72,788 $ 59,854 $ 195,531 $ 78,445 Basic weighted average Class A Shares outstanding 179,197 155,001 173,322 91,183 Equity Participation Shares equivalent shares 958 1,087 1,434 1,478 Diluted weighted average Class A Shares outstanding 180,155 156,088 174,756 92,661 Diluted net income per Class A Share $ 0.40 $ 0.38 $ 1.12 $ 0.85

Regulatory Matters

Regulatory Matters	9 Months Ended
	Sep. 30, 2019
Regulated Operations [Abstract]
Regulatory Matters	There are no regulatory proceedings challenging the rates of Pony Express and Rockies Express. On May 1, 2019, as further described below, TIGT filed with the FERC a pre–filing settlement that establishes, among other things, settlement rates for supporting/non–contesting participants as defined in the pre–filing settlement. On June 29, 2018, Trailblazer Pipeline Company LLC ("Trailblazer") filed a general rate case with the FERC pursuant to Section 4 of the Natural Gas Act ("NGA"), as further described below. We have also made certain other regulatory filings with the FERC, including those further described below. Pony Express Pony Express Local and Volume Incentive Rate Filing - FERC Docket No. IS20-3-000 On October 1, 2019, Pony Express filed with the FERC to establish three volume incentive programs that provide uncommitted shippers the ability to access lower rates depending on the volumes shipped. The establishment of the volume incentive programs caused a corresponding reduction in committed shipper rates from Guernsey, Wyoming to destinations in Kansas and Oklahoma. Pony Express proposed an effective date of November 1, 2019 for these changes. Rockies Express Cheyenne Hub Enhancement Project - FERC Docket No. CP18-103-000 On March 2, 2018, Rockies Express submitted an application pursuant to section 7(c) of the NGA for a certificate of public convenience and necessity authorizing the construction and operation of certain booster compressor units and ancillary facilities located at the Cheyenne Hub in Weld County, Colorado that will enable Rockies Express to provide a new hub service allowing for firm receipts and deliveries between Rockies Express and certain other interconnected pipelines at the Cheyenne Hub. Rockies Express filed this certificate application in conjunction with a concurrently filed certificate application by Cheyenne Connector, LLC ("Cheyenne Connector") for the Cheyenne Connector Pipeline Project further described below. The comment period for the Cheyenne Hub Enhancement Project closed on April 9, 2018. To date, various comments have been filed by market participants and others regarding the proposed project. Rockies Express has also responded to data requests from the FERC's relevant program offices. On October 11, 2018, the FERC issued a Notice of Schedule of Environmental Review setting December 18, 2018 as the date of issuance of the Environmental Assessment and March 18, 2019 as the deadline for decisions by other federal agencies on requests for authorizations for the proposed project. On December 18, 2018, the FERC issued the Environmental Assessment. On September 20, 2019, the FERC issued an order approving the application. A notice to proceed with construction was issued on October 8, 2019. Cheyenne Connector Cheyenne Connector Pipeline Project - FERC Docket No. CP18-102-000 On March 2, 2018, Cheyenne Connector, an indirect subsidiary of TGE, submitted an application pursuant to section 7(c) of the NGA for a certificate of public convenience and necessity to construct and operate a 70 -mile, 36 -inch pipeline to transport natural gas from multiple gas processing plants in Weld County, Colorado to Rockies Express' Cheyenne Hub. The comment period for the Cheyenne Connector Pipeline Project closed on April 9, 2018. To date, various comments have been filed by market participants and others regarding the proposed project. Cheyenne Connector has also responded to data requests from the FERC's relevant program offices. On October 11, 2018, the FERC issued a Notice of Schedule of Environmental Review setting December 18, 2018 as the date of issuance of the Environmental Assessment and March 18, 2019 as the deadline for decisions by other federal agencies on requests for authorizations for the proposed project. On December 18, 2018, the FERC issued the Environmental Assessment. On September 20, 2019, the FERC issued an order approving the application. A notice to proceed with construction was issued on October 8, 2019. TIGT Pre-Filing Settlement - FERC Docket No. RP19-423-001 On May 1, 2019, TIGT filed a contested pre-filing settlement that, consistent with Article II.B.1 of the 2016 rate case settlement approved in Docket No. RP16-137-000, satisfies TIGT's mandatory rate case filing requirement under Article II.B.1 of such settlement. The pre-filing settlement establishes, among other things, settlement rates reflecting an overall decrease to recourse rates, contract extensions for maximum recourse rate firm contracts through May 31, 2023, and a rate moratorium period through May 31, 2023. The settlement also requires that TIGT file a new NGA Section 4 general rate case on June 1, 2023, provided that TIGT has not preempted this mandatory filing requirement by filing on or before June 1, 2023 for approval of a new pre-filing settlement. TIGT has also requested that the FERC terminate the pending Form No. 501-G proceeding in Docket No. RP19-423-000 upon approval of the pre-filing settlement. On September 24, 2019, the FERC issued an order establishing settlement judge procedures to afford the parties an opportunity to resolve contested issues via settlement. On October 15, 2019, the party contesting the settlement notified the FERC that it no longer objects to the settlement, it has reached a mutually agreeable accommodation with TIGT, and settlement judge procedures are not required. Further action by the FERC on the settlement is pending. Trailblazer General Rate Case Filing - FERC Docket No. RP18-922-000, et seq. On June 29, 2018, Trailblazer filed a general rate case with the FERC, which satisfies the requirement set forth in the settlement resolving Trailblazer's previous general rate case that Trailblazer file a new general rate case with rates to be effective no later than January 1, 2019. The June 29, 2018 filing reflects an overall increase to Trailblazer's cost of service. In the filing, Trailblazer is proposing to maintain its existing bifurcated firm transportation service rate design as well as its current tracking methodologies for the treatment of Fuel and Lost and Unaccounted For ("FL&U") gas and electric power costs. The proposed rates include an increase in rates on Trailblazer's Existing System Firm Transportation Service. The overall rate increase would be partially offset by a proposed decrease in rates for Expansion System Firm Transportation Service and interruptible services. Trailblazer is also proposing to include a cost recovery mechanism in its tariff to recover future eligible costs related to system safety, integrity, reliability, environmental and cybersecurity issues. Under the NGA and the FERC's regulations, Trailblazer's shippers and other interested parties, including the FERC's Trial Staff, have the right to challenge any aspect of Trailblazer's rate case filing. On July 11, 2018, four protests were filed that challenge various aspects of Trailblazer's rate case filing. On July 31, 2018, the FERC issued an order accepting and suspending the rate case filing, and establishing hearing and settlement procedures. In the order, the FERC approved the as-filed rate decreases for Expansion System Firm Transportation Service, as well as Trailblazer's interruptible services, effective August 1, 2018. The FERC also established a paper hearing to examine the extent to which Trailblazer is entitled to an income tax allowance. All remaining issues, including the proposed rate increases to Existing System Firm Transportation Service, were set for an administrative law judge hearing and accepted effective January 1, 2019, subject to refund. On December 31, 2018, Trailblazer filed a motion with FERC to move the suspended tariff records into effect as of January 1, 2019. Trailblazer and certain of its shippers sought rehearing of the July 31, 2018 order. On July 2, 2019, the FERC issued an order on rehearing and clarification dismissing in part and denying in part the requests for rehearing and clarification, but granting Trailblazer's request for clarification that it may implement any resulting increases and decreases in the rates of its two systems in a single compliance filing at the conclusion of the proceeding. On February 21, 2019, the FERC issued an order following the paper hearing on the income tax allowance issue, making a preliminary finding that a double recovery appears to result from permitting an income tax allowance for the income tax liability attributable to certain private owners' ownership share in Trailblazer in addition to a discounted cash flow return on equity. The FERC also preliminarily found that no double recovery resulted from permitting an income tax allowance for the corporate income tax liability attributable to TGE's ownership share in Trailblazer in addition to a discounted cash flow return on equity. The FERC ordered that the income tax allowance be addressed at the administrative law judge hearing with the other remaining issues, and its initial findings may change based upon subsequent evidence and argument. In March 2019, the Chief Administrative Law Judge terminated settlement judge procedures and established the procedural time standards for the administrative law judge hearing, with the hearing currently scheduled to begin in January 2020. On October 2, 2019, a settlement in principle was reached with all parties in the proceeding. The settlement in principle is subject to certification by the Presiding Administrative Law Judge and approval of the FERC.

Legal and Environmental Matters

Legal and Environmental Matters	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Legal and Environmental Matters	Legal In addition to the matters discussed below, we are a defendant in various lawsuits arising from the day-to-day operations of our business. Although no assurance can be given, we believe, based on our experiences to date, that the ultimate resolution of such matters will not have a material adverse impact on our business, financial position, results of operations, or cash flows. We have evaluated claims in accordance with the accounting guidance for contingencies that we deem both probable and reasonably estimable and, accordingly, have recorded no reserve for legal claims as of September 30, 2019 or December 31, 2018 . Rockies Express EM Energy Ohio, LLC On May 15, 2019, EM Energy Ohio, LLC ("EM Energy") and certain of its affiliates filed for protection under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware. EM Energy had a firm transportation service agreement with Rockies Express for 50,000 Dth/d through January 5, 2032. Rockies Express and EM Energy have stipulated in the bankruptcy proceeding that the termination date of the transportation service agreement is June 13, 2019. Following the termination, Rockies Express made a drawing equal to the outstanding face amount on the letter of credit supporting EM Energy's obligations under the transportation service agreement and received approximately $16.2 million in June 2019. A portion of the proceeds was used to settle outstanding accounts receivable for transportation services provided to EM Energy and the remaining $13.9 million was recognized as income by Rockies Express. Rockies Express intends to pursue its claim against the bankruptcy estate of EM Energy for damages and to remarket the capacity resulting from the termination of the transportation service agreement. Ohio Public Utility Excise Tax The Ohio Tax Commissioner has assessed Rockies Express a public utility excise tax on transactions concerning product that entered and exited Rockies Express within the state of Ohio. This tax applies to gross receipts from all business conducted within the state, but exempts all receipts derived wholly from interstate business. Rockies Express has disputed any obligation to pay Ohio's public utility excise tax, but has paid the taxes as assessed in order to preserve its right to appeal. The dispute is currently pending before the Ohio Supreme Court, with a final decision anticipated by early 2020. It is Rockies Express' position that the relevant statute exempts receipts derived wholly from interstate business from the public utility excise tax. The Ohio Supreme Court and the United States Supreme Court have both held that, once it enters an interstate pipeline, natural gas is moving in "interstate commerce" for the duration of its journey until it is delivered to a local distribution system. As of September 30, 2019 , Rockies Express has paid public utility excise taxes to the state of Ohio totaling $7.1 million and has accrued an additional $7.1 million for amounts expected to be assessed for the period from May 1, 2018 through September 30, 2019 . While it is difficult to accurately predict how the Ohio Supreme Court will decide the case, Rockies Express is optimistic about the ultimate outcome and has recorded a $14.2 million asset representing the anticipated refund of the public utility excise taxes assessed. Environmental, Health and Safety We are subject to a variety of federal, state and local laws that regulate permitted activities relating to air and water quality, waste disposal, and other environmental matters. We currently believe that compliance with these laws will not have a material adverse impact on our business, cash flows, financial position or results of operations. However, there can be no assurances that future events, such as changes in existing laws, the promulgation of new laws, or the development of new facts or conditions will not cause us to incur significant costs. We had environmental reserves of $6.4 million and $7.4 million at September 30, 2019 and December 31, 2018 , respectively. Rockies Express Seneca Lateral On January 31, 2018, Rockies Express experienced an operational disruption on its Seneca Lateral due to a pipe rupture and natural gas release in a rural area in Noble County, Ohio. There were no injuries reported and no evacuations. The release required Rockies Express to shut off the flow through the segment until February 27, 2018, when temporary repairs were completed, allowing the segment to be placed back into service. Permanent repairs were completed in September 2018. Total cost of remediation was approximately $6.1 million , $5.1 million of which Rockies Express has recovered through insurance. TMID and TIGT Casper Plant, EPA Notice of Violation In August 2011, the EPA and the Wyoming Department of Environmental Quality ("WDEQ") conducted an inspection of the Leak Detection and Repair ("LDAR") Program at the Casper Gas Plant in Wyoming. In September 2011, TMID received a letter from the EPA alleging violations of the Standards of Performance of Equipment Leaks for Onshore Natural Gas Processing Plant requirements under the Clean Air Act. TMID received a letter from the EPA concerning settlement of this matter in April 2013 and received additional settlement communications from the EPA and Department of Justice beginning in July 2014. TMID and TIGT entered into a Consent Agreement and Final Order to settle this matter with the EPA on February 21, 2019 and made an approximately $0.1 million penalty payment to the EPA. Casper Gas Plant On November 25, 2014, the WDEQ issued a Notice of Violation for violations of Part 60 Subpart OOOO related to the Depropanizer project (wv-14388, issued 7/9/13) in Docket No. 5506-14. TMID had discussed the issues in a meeting with WDEQ in Cheyenne on November 17, 2014, and submitted a disclosure on November 20, 2014 detailing the regulatory issues and potential violations. The project triggered a modification of Subpart OOOO for the entire plant. The project equipment as well as plant equipment subjected to Subpart OOOO was not monitored timely, and initial notification was not made timely. TMID and TIGT entered into a Consent Decree to settle this matter with the WDEQ on March 8, 2019 and made an approximately $0.1 million penalty payment to the WDEQ. TMG Archibald Booster Station Tallgrass Midstream Gathering, LLC ("TMG") is currently a party to a remedy agreement entered into with the WDEQ in July 2013 with respect to the Archibald Booster Station located in Campbell County, Wyoming. In connection with the remedy agreement, TMG has agreed to complete certain remedial actions at the site related to a former earthen pit including semi-annual groundwater sampling, and quarterly recovery activities at monitoring wells. The facility is currently in compliance with the WDEQ under the remedy agreement. Irwin Booster Station TMG is also party to a remedy agreement entered into with the WDEQ in July 2013 with respect to the Irwin Booster Station located in Converse County, Wyoming. In connection with the remedy agreement, TMG has agreed to complete certain remedial actions at the site related to a former earthen pit including semi-annual groundwater sampling. The facility is currently in compliance with the WDEQ under the remedy agreement.

Reporting Segments

Reporting Segments	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Reporting Segments	Our operations are located in the United States. We are organized into three reportable segments: (1) Natural Gas Transportation, (2) Crude Oil Transportation, and (3) Gathering, Processing & Terminalling. Corporate and Other includes corporate overhead costs that are not directly associated with the operations of our reportable segments, such as interest and fees associated with our revolving credit facility and the Senior Notes, public company costs, equity-based compensation expense, and eliminations of intersegment activity. Natural Gas Transportation. The Natural Gas Transportation segment is engaged in the ownership and operation of FERC-regulated interstate natural gas pipelines and an integrated natural gas storage facility that provide services to on-system customers (such as third-party LDCs), industrial users and other shippers. The Natural Gas Transportation segment includes our 75% membership interest in Rockies Express . Crude Oil Transportation. The Crude Oil Transportation segment is engaged in the ownership and operation of the Pony Express System, which is a FERC-regulated crude oil pipeline serving the Bakken Shale, Denver-Julesburg and Powder River Basins, and other nearby oil producing basins. The Crude Oil Transportation segment includes our 51% membership interest in Powder River Gateway . Gathering, Processing & Terminalling. The Gathering, Processing & Terminalling segment is engaged in the ownership and operation of natural gas gathering and processing facilities that produce NGLs and residue gas sold in local wholesale markets or delivered into pipelines for transportation to additional end markets; our crude oil terminal services; water business services provided primarily to the oil and gas exploration and production industry; the transportation of NGLs; and Stanchion. The Gathering, Processing & Terminalling segment includes our 51% membership interest in Pawnee Terminal, LLC ("Pawnee Terminal"). These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for their respective operations. We consider Adjusted EBITDA to be our primary segment performance measure as we believe it is the most meaningful measure to assess our financial condition and results of operations as a public entity. We define Adjusted EBITDA as net income excluding the impact of interest, income taxes, depreciation and amortization, non-cash income or loss related to derivative instruments, non-cash long-term compensation expense, impairment losses, gains or losses on asset or business disposals or acquisitions, gains or losses on the repurchase, redemption or early retirement of debt, and earnings from unconsolidated investments, but including the impact of distributions from unconsolidated investments and deficiency payments received from or utilized by our customers. Adjusted EBITDA is calculated and presented at the Tallgrass Equity level, before consideration of noncontrolling interest associated with the Exchange Right Holders, which we believe provides investors the most complete and comparable picture of our overall financial and operational results. The following tables set forth our segment information for the periods indicated: Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 32,808 $ (490 ) $ 32,318 $ 34,077 $ (816 ) $ 33,261 Crude Oil Transportation 126,787 (14,415 ) 112,372 116,250 (13,579 ) 102,671 Gathering, Processing & Terminalling 90,843 (8,824 ) 82,019 71,612 (7,224 ) 64,388 Corporate and Other — — — — — — Total revenue $ 250,438 $ (23,729 ) $ 226,709 $ 221,939 $ (21,619 ) $ 200,320 Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 103,521 $ (1,391 ) $ 102,130 $ 105,208 $ (4,136 ) $ 101,072 Crude Oil Transportation 356,741 (44,774 ) 311,967 319,008 (26,323 ) 292,685 Gathering, Processing & Terminalling 245,639 (24,151 ) 221,488 199,062 (19,816 ) 179,246 Corporate and Other — — — — — — Total revenue $ 705,901 $ (70,316 ) $ 635,585 $ 623,278 $ (50,275 ) $ 573,003 Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 142,158 $ (1,163 ) $ 140,995 $ 121,433 $ (1,460 ) $ 119,973 Crude Oil Transportation 88,202 (4,527 ) 83,675 87,567 (5,008 ) 82,559 Gathering, Processing & Terminalling 35,611 5,690 41,301 13,679 6,468 20,147 Corporate and Other (2,203 ) — (2,203 ) (2,317 ) — (2,317 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 86,349 76,268 Non-cash gain related to derivative instruments (1) 1,928 2,993 Gain on disposal of assets (1) — 279 Less: Interest expense, net (1) (41,630 ) (34,019 ) Depreciation and amortization expense (1) (31,500 ) (27,356 ) Distributions from unconsolidated investments (1) (129,122 ) (100,720 ) Non-cash compensation expense (1) (2,951 ) (2,767 ) Deficiency payments, net (1) 2,329 (3,468 ) Loss on debt retirement — (2,245 ) Income tax expense (1) (22,563 ) (11,997 ) Net income attributable to Exchange Right Holders (54,084 ) (57,780 ) Net income attributable to TGE $ 72,524 $ 59,550 Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 425,286 $ (3,253 ) $ 422,033 $ 253,169 $ (2,940 ) $ 250,229 Crude Oil Transportation 258,900 (17,681 ) 241,219 150,943 (3,857 ) 147,086 Gathering, Processing & Terminalling 87,380 20,934 108,314 30,002 6,797 36,799 Corporate and Other (7,771 ) — (7,771 ) (20,819 ) — (20,819 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 273,883 153,235 Non-cash gain related to derivative instruments (1) 899 3,306 Gain on disposal of assets (1) — 3,388 Less: Interest expense, net (1) (121,941 ) (57,208 ) Depreciation and amortization expense (1) (94,819 ) (45,794 ) Distributions from unconsolidated investments (1) (369,690 ) (198,019 ) Non-cash compensation expense (1) (23,521 ) (4,738 ) Deficiency payments, net (1) (14,241 ) (7,205 ) Loss on debt retirement — (2,245 ) Income tax expense (1) (61,606 ) (35,498 ) Net income attributable to Exchange Right Holders (158,029 ) (145,169 ) Net income attributable to TGE $ 194,730 $ 77,348 (1) Net of noncontrolling interest associated with less than wholly-owned subsidiaries of Tallgrass Equity. Nine Months Ended September 30, Capital Expenditures: 2019 2018 (in thousands) Natural Gas Transportation $ 75,478 $ 96,290 Crude Oil Transportation 78,379 39,847 Gathering, Processing & Terminalling 66,411 125,866 Corporate and Other 5,194 3,070 Total capital expenditures $ 225,462 $ 265,073 Assets: September 30, 2019 December 31, 2018 (in thousands) Natural Gas Transportation $ 2,624,490 $ 2,606,696 Crude Oil Transportation 1,758,450 1,423,740 Gathering, Processing & Terminalling 1,580,752 1,522,559 Corporate and Other 239,205 340,514 Total assets $ 6,202,897 $ 5,893,509

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
Subsequent Events	Cheyenne Connector On October 28, 2019, a subsidiary of DCP Midstream, LP ("DCP") exercised its option to purchase a 50% membership interest in Cheyenne Connector, which is currently developing the Cheyenne Connector Pipeline Project as discussed in Note 15 – Regulatory Matters . The closing of DCP's option is expected in the fourth quarter of 2019, subject to certain closing conditions. Following the closing, we will own a 50% membership interest and continue to operate the Cheyenne Connector joint venture.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation These condensed consolidated financial statements and related notes for the three and nine months ended September 30, 2019 and 2018 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board's Accounting Standards Codification, the single source of accounting principles generally accepted in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP for annual periods. The condensed consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair statement of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Our financial results for the three and nine months ended September 30, 2019 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2019 . The accompanying condensed consolidated interim financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018 ("2018 Form 10-K") filed with the SEC on February 8, 2019.
Consolidation	The condensed consolidated financial statements include the accounts of TGE and its subsidiaries and controlled affiliates. Intra-entity items have been eliminated in the presentation. Net income or loss from consolidated subsidiaries that are not wholly-owned by TGE is attributed to TGE and noncontrolling interests in accordance with the respective ownership interests. We have no elements of other comprehensive income for the periods presented.
Use of Estimates	Use of Estimates Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.
Income Tax, Policy	Income Taxes During the nine months ended September 30, 2019 , we recognized an additional deferred tax asset of $123.1 million upon exercise of the Exchange Right, as discussed in Note 11 – Partnership Equity , with respect to 21,751,018 Class B shares to Class A shares in connection with the Blackstone Acquisition discussed in Note 1 – Description of Business . As a result of the increased income allocated to TGE resulting from our increased ownership in TEP following the merger transaction effective June 30, 2018 and the exercise of the Exchange Right effective March 11, 2019, our annual effective tax rate increased from 9.02% for the nine months ended September 30, 2018 to 14.79% for the nine months ended September 30, 2019 . As discussed in Note 3 – Acquisitions , a newly formed indirect subsidiary of TGE acquired the outstanding stock of an entity classified as a C corporation for U.S. federal income tax purposes effective May 1, 2019. As a result, we recognized approximately $237,000 of current income taxes during the three months ended September 30, 2019 .
Accounting Pronouncements	Accounting Pronouncement Recently Adopted ASU No. 2016-02, "Leases (Topic 842)" In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). ASU 2016-02 provides a comprehensive update to the lease accounting topic in the Codification intended to increase transparency and comparability among organizations by recognizing right-of-use ("ROU") assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The amendments in ASU 2016-02 include a revised definition of a lease as well as certain scope exceptions. The changes primarily impact lessee accounting, while lessor accounting is largely unchanged from previous GAAP. Management has completed its evaluation and implemented the revised guidance using the modified retrospective method as of January 1, 2019. This approach allows us to (i) initially apply ASC 842 at the adoption date, January 1, 2019 and (ii) continue reporting comparative periods presented in the financial statements in the period of adoption under ASC 840. Accordingly, we will not recast comparative periods in the condensed consolidated financial statements. We have elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed us to carry forward the historical lease classification. We have also elected the following practical expedients: (a) the land easement practical expedient, allowing us to carry forward our accounting treatment for existing land easements as property, plant and equipment, (b) the practical expedient for short-term leases, allowing us to not recognize ROU assets or lease liabilities for leases with a term of 12 months or less, and (c) for agreements that contain both lease and non-lease components, combining these components together and accounting for them as a single lease. Excluding ROU assets and lease liabilities relating to agreements between consolidated subsidiaries, adoption of the new standard resulted in the recognition of ROU assets of approximately $2.3 million , and current and non-current lease liabilities of approximately $0.6 million and $1.7 million , respectively, for operating leases as of January 1, 2019. Our accounting for finance leases remained substantially unchanged. The adoption of this guidance had no impact to our cash flows from operating, investing, or financing activities. For additional information see Note 13 – Leases . Accounting Pronouncements Not Yet Adopted ASU No. 2016-13, "Financial Instruments–Credit Losses (Topic 326)" In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments–Credit Losses (Topic 326). ASU 2016-13 amends current measurement techniques used to estimate credit losses for financial assets. The amendments in ASU 2016-13 are effective for financial statements issued for annual periods beginning after December 15, 2019, and interim periods within those annual periods. Early adoption is permitted. We are currently evaluating the impact of ASU 2016-13 but do not anticipate a material impact on our consolidated financial statements.

Leases (Policies)

Leases (Policies)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Lessee, Leases	Under ASC 842, a contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. We assess whether an arrangement is or contains a lease at inception of the contract. For all leases (finance and operating leases), other than those that qualify for the short-term recognition exemption, we recognize as of the lease commencement date on the balance sheet a liability for our obligation related to the lease and a corresponding asset representing our right to use the underlying asset over the period of use. The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As most of our leases do not provide an implicit rate, we determine the appropriate discount rate using our incremental secured borrowing rate, with consideration given to the nature and term of the leased asset.
Lessor, Leases	Under ASC 842, a contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. We assess whether an arrangement is or contains a lease at inception of the contract. For all leases (finance and operating leases), other than those that qualify for the short-term recognition exemption, we recognize as of the lease commencement date on the balance sheet a liability for our obligation related to the lease and a corresponding asset representing our right to use the underlying asset over the period of use. The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As most of our leases do not provide an implicit rate, we determine the appropriate discount rate using our incremental secured borrowing rate, with consideration given to the nature and term of the leased asset.

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2019
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information	Unaudited pro forma revenue and net income attributable to TGE for the three and nine months ended September 30, 2019 and 2018 is presented below as if the acquisition of CES had been completed on January 1, 2018. Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Revenue $ 226,709 $ 205,016 $ 640,377 $ 583,788 Net income attributable to TGE $ 72,524 $ 60,641 $ 195,565 $ 78,695
CES Holding Company, Inc.
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following represents the fair value of assets acquired and liabilities assumed: Preliminary Adjustments Final (in thousands) Accounts receivable $ 1,391 $ — $ 1,391 Prepayments 67 — 67 Property, plant and equipment 6,900 4,400 11,300 Intangible asset 35,800 (2,900 ) 32,900 (1) Accounts payable and accrued liabilities (1,518 ) — (1,518 ) (2) Deferred tax liability (8,557 ) (189 ) (8,746 ) Net identifiable assets acquired 34,083 1,311 35,394 Goodwill 17,734 (1,311 ) 16,423 Net assets acquired (excluding cash) $ 51,817 $ — $ 51,817 (1) The $32.9 million intangible asset acquired represents customer relationships and is amortized on a straight-line basis over a period of 8 years. (2) Includes the estimated fair value of the liability for contingent consideration of $0.7 million .
NGL Water Solutions Bakken, LLC
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following represents the fair value of assets acquired and liabilities assumed: Preliminary Adjustments Final (in thousands) Accounts receivable $ 3,599 $ (3,599 ) $ — Prepayments and other current assets 5 — 5 Property, plant and equipment 17,200 — 17,200 Intangible asset 54,000 — 54,000 Accounts payable and accrued liabilities (949 ) 644 (305 ) Net identifiable assets acquired 73,855 (2,955 ) 70,900 Goodwill 17,145 2,955 20,100 Net assets acquired $ 91,000 $ — $ 91,000

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Schedule of Transactions with Affiliated Companies	Totals of transactions with affiliated companies, excluding transactions disclosed elsewhere in these notes, are as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Processing and other revenues (1) $ 2,020 $ 1,838 $ 5,830 $ 5,603 Cost of transportation services (2) $ 210 $ — $ 730 $ — (1) Reflects the fee that NatGas receives as the operator of the Rockies Express Pipeline. (2) Reflects rent expense for crude oil storage and terminalling services provided by Powder River Gateway. Details of balances with affiliates included in "Accounts receivable, net" in the condensed consolidated balance sheets are as follows: September 30, 2019 December 31, 2018 (in thousands) Receivable from related parties: Rockies Express Pipeline LLC $ 2,900 $ 3,447 Powder River Gateway, LLC 379 — Pawnee Terminal, LLC 100 115 Iron Horse Pipeline, LLC — 186 Total receivable from related parties $ 3,379 $ 3,748 Details of gas imbalances with affiliated shippers included in "Prepayments and other current assets" and "Other current liabilities" in the condensed consolidated balance sheets are as follows: September 30, 2019 December 31, 2018 (in thousands) Affiliate gas imbalance receivables $ 30 $ 19 Affiliate gas imbalance payables $ 875 $ 742

Inventory - (Tables)

Inventory - (Tables)	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Schedule of Components of Inventory	The components of inventory at September 30, 2019 and December 31, 2018 consisted of the following: September 30, 2019 December 31, 2018 (in thousands) Crude oil $ 30,158 $ 23,205 Materials and supplies 7,747 8,206 Gas in underground storage 2,650 2,740 Natural gas liquids 473 165 Total inventory $ 41,028 $ 34,316

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Components of Property Plant and Equipment	A summary of net property, plant and equipment by classification is as follows: September 30, 2019 December 31, 2018 (in thousands) Crude oil pipelines $ 1,365,353 $ 1,313,976 Gathering, processing and terminalling assets 970,749 889,168 Natural gas pipelines 624,489 607,343 General and other (1) 172,708 180,299 Construction work in progress 188,320 191,994 Accumulated depreciation and amortization (456,512 ) (380,351 ) Total property, plant and equipment, net $ 2,865,107 $ 2,802,429 (1) Includes approximately $30.7 million of land associated with the PLT capital lease as discussed in Note 13 – Leases .

Investments in Unconsolidated_2

Investments in Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Summarized financial information for Rockies Express is as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Revenue $ 233,010 $ 225,753 $ 696,094 $ 683,426 Operating income $ 130,908 $ 127,119 $ 397,629 $ 385,831 Net income to Members $ 100,968 $ 90,707 $ 322,212 $ 270,338

Goodwill (Tables)

Goodwill (Tables)	9 Months Ended
	Sep. 30, 2019
Goodwill [Abstract]
Schedule of Goodwill	Reconciliation of Goodwill The following table presents a reconciliation of the carrying amount of goodwill by reportable segment for the reporting period: Natural Gas Transportation Gathering, Processing & Terminalling Total (in thousands) Balance at December 31, 2018 $ 255,558 $ 166,425 $ 421,983 Goodwill acquired — 16,423 (1) 16,423 Other adjustments — 2,955 (2) 2,955 Balance at September 30, 2019 $ 255,558 $ 185,803 $ 441,361 (1) The $16.4 million of goodwill was recorded in connection with the acquisition of CES on May 1, 2019 as discussed further in Note 3 – Acquisitions . (2) The $3.0 million goodwill adjustment was recorded in connection with a purchase price allocation adjustment related to the NGL Water Solutions Bakken acquisition as discussed further in Note 3 – Acquisitions .

Risk Management (Tables)

Risk Management (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Fair Value of Derivative Contracts	The following table summarizes the fair values of our derivative contracts included in the condensed consolidated balance sheets: Balance Sheet Location September 30, 2019 December 31, 2018 (in thousands) Crude oil derivative contracts Prepayments and other current assets $ 4,015 $ 3,526 Crude oil derivative contracts Other current liabilities $ 454 $ 1,642 As of September 30, 2019 , the amounts shown represent the fair value of crude oil derivative contracts for the forward purchase of 2,157,325 and the forward sale of 4,349,000 barrels of crude oil consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020. As of December 31, 2018 , the amounts shown represent the fair value of crude oil derivative contracts for the forward purchase of 2,105,146 and the forward sale of 1,274,500 barrels of crude oil consisting of fixed price and floating price contracts, which will settle throughout 2019.
Derivative Contracts Included in Consolidated Statements of Income	The following table summarizes the impact of derivative contracts not designated as hedging contracts for the three and nine months ended September 30, 2019 and 2018 : Location of gain recognized Amount of gain recognized in income on derivatives Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands) Crude oil derivative contracts Sales of natural gas, NGLs, and crude oil $ 14,574 $ 9,435 $ 40,631 $ 16,665
Derivative Instruments Maximum Potential Exposure to Credit Loss	The maximum potential exposure to credit losses on our crude oil derivative contracts at September 30, 2019 was: Asset Position (in thousands) Gross $ 4,015 Netting agreement impact — Cash collateral held — Net exposure $ 4,015
Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification	The following table summarizes the fair value measurements of our derivative contracts as of September 30, 2019 and December 31, 2018 , based on the fair value hierarchy: Asset Fair Value Measurements Using Total Quoted prices in Significant Significant (in thousands) As of September 30, 2019: Crude oil derivative contracts $ 4,015 $ — $ 4,015 $ — As of December 31, 2018: Crude oil derivative contracts $ 3,526 $ — $ 3,526 $ — Liability Fair Value Measurements Using Total Quoted prices in Significant Significant (in thousands) As of September 30, 2019: Crude oil derivative contracts $ 454 $ — $ 454 $ — As of December 31, 2018: Crude oil derivative contracts $ 1,642 $ — $ 1,642 $ —

Long-term Debt (Tables)

Long-term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of Debt	Our long-term debt is held at TEP and consisted of the following at September 30, 2019 and December 31, 2018 : September 30, 2019 December 31, 2018 (in thousands) Revolving credit facility $ 1,467,000 $ 1,224,000 4.75% senior notes due October 1, 2023 500,000 500,000 5.50% senior notes due September 15, 2024 750,000 750,000 5.50% senior notes due January 15, 2028 750,000 750,000 Less: Deferred financing costs, net (1) (18,848 ) (21,421 ) Plus: Unamortized premium on 2028 Notes 3,116 3,379 Total long-term debt, net $ 3,451,268 $ 3,205,958 (1) Deferred financing costs, net as presented above relate solely to the Senior Notes (as defined below). Deferred financing costs associated with our revolving credit facility are presented in noncurrent assets on our condensed consolidated balance sheets.
Schedule of Line of Credit Facility	The following table sets forth the available borrowing capacity under our revolving credit facility as of September 30, 2019 and December 31, 2018 : September 30, 2019 December 31, 2018 (in thousands) Total capacity under the revolving credit facility $ 2,250,000 $ 2,250,000 Less: Outstanding borrowings under the revolving credit facility (1,467,000 ) (1,224,000 ) Less: Letters of credit issued under the revolving credit facility (94 ) (94 ) Available capacity under the revolving credit facility $ 782,906 $ 1,025,906
Carrying Amount and Fair value of Long-term Debt	The following table sets forth the carrying amount and fair value of long-term debt, which is not measured at fair value in the condensed consolidated balance sheets as of September 30, 2019 and December 31, 2018 , but for which fair value is disclosed: Fair Value Quoted prices Significant Significant Total Carrying (in thousands) As of September 30, 2019: Revolving credit facility $ — $ 1,467,000 $ — $ 1,467,000 $ 1,467,000 2023 Notes $ — $ 502,135 $ — $ 502,135 $ 495,466 2024 Notes $ — $ 748,305 $ — $ 748,305 $ 742,344 2028 Notes $ — $ 735,998 $ — $ 735,998 $ 746,458 As of December 31, 2018: Revolving credit facility $ — $ 1,224,000 $ — $ 1,224,000 $ 1,224,000 2023 Notes $ — $ 485,285 $ — $ 485,285 $ 494,603 2024 Notes $ — $ 737,745 $ — $ 737,745 $ 741,196 2028 Notes $ — $ 726,503 $ — $ 726,503 $ 746,159

Partnership Equity - Dividends

Partnership Equity - Dividends Declared (Tables)	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Dividends Declared	The following table details the dividends for the periods indicated: Three Months Ended Date Paid Dividends to Class A Shareholders Dividends per Class A Share (in thousands, except per share amounts) September 30, 2019 November 14, 2019 (1) $ 98,559 $ 0.5500 June 30, 2019 August 14, 2019 96,767 0.5400 March 31, 2019 May 15, 2019 94,975 0.5300 December 31, 2018 February 14, 2019 81,304 0.5200 September 30, 2018 November 14, 2018 79,717 0.5100 June 30, 2018 August 14, 2018 77,052 0.4975 March 31, 2018 May 15, 2018 28,316 0.4875 (1) The dividend announced on October 10, 2019 for the third quarter of 2019 will be paid on November 14, 2019 to Class A shareholders of record at the close of business on October 31, 2019 .

Revenue from Contracts with C_2

Revenue from Contracts with Customers - (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	A summary of our revenue by line of business is as follows: Three Months Ended September 30, 2019 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 111,572 $ — $ — $ 111,572 Natural gas transportation - firm service 30,066 — — (490 ) 29,576 Water business services — — 31,311 — 31,311 Natural gas gathering & processing fees — — 7,021 — 7,021 All other (1) 2,742 15,215 5,425 (18,836 ) 4,546 Total service revenue 32,808 126,787 43,757 (19,326 ) 184,026 Natural gas liquids sales — — 16,256 — 16,256 Natural gas sales — — 8,932 — 8,932 Crude oil sales — — 138 — 138 Total commodity sales revenue — — 25,326 — 25,326 Total revenue from contracts with customers 32,808 126,787 69,083 (19,326 ) 209,352 Other revenue (2) — — 21,760 (4,403 ) 17,357 Total revenue (3) $ 32,808 $ 126,787 $ 90,843 $ (23,729 ) $ 226,709 Nine Months Ended September 30, 2019 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 306,288 $ — $ — $ 306,288 Natural gas transportation - firm service 94,571 — — (1,374 ) 93,197 Water business services — — 80,896 — 80,896 Natural gas gathering & processing fees — — 18,431 — 18,431 All other (1) 8,831 45,723 12,689 (54,584 ) 12,659 Total service revenue 103,402 352,011 112,016 (55,958 ) 511,471 Natural gas liquids sales — — 46,303 — 46,303 Natural gas sales 119 — 24,441 — 24,560 Crude oil sales — 4,730 384 — 5,114 Total commodity sales revenue 119 4,730 71,128 — 75,977 Total revenue from contracts with customers 103,521 356,741 183,144 (55,958 ) 587,448 Other revenue (2) — — 62,495 (14,358 ) 48,137 Total revenue (3) $ 103,521 $ 356,741 $ 245,639 $ (70,316 ) $ 635,585 Three Months Ended September 30, 2018 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 100,614 $ — $ — $ 100,614 Natural gas transportation - firm service 31,070 — — (793 ) 30,277 Water business services — — 12,837 — 12,837 Natural gas gathering & processing fees — — 6,631 — 6,631 All other (1) 2,551 13,321 6,709 (17,636 ) 4,945 Total service revenue 33,621 113,935 26,177 (18,429 ) 155,304 Natural gas liquids sales — — 26,201 — 26,201 Natural gas sales 456 — 5,517 — 5,973 Crude oil sales — 2,315 147 — 2,462 Total commodity sales revenue 456 2,315 31,865 — 34,636 Total revenue from contracts with customers 34,077 116,250 58,042 (18,429 ) 189,940 Other revenue (2) — — 13,570 (3,190 ) 10,380 Total revenue (3) $ 34,077 $ 116,250 $ 71,612 $ (21,619 ) $ 200,320 Nine Months Ended September 30, 2018 Natural Gas Transportation segment Crude Oil Transportation segment Gathering, Processing, & Terminalling segment Corporate and Other Total Revenue (in thousands) Crude oil transportation - committed shipper revenue $ — $ 286,594 $ — $ — $ 286,594 Natural gas transportation - firm service 96,166 — — (4,074 ) 92,092 Water business services — — 38,246 — 38,246 Natural gas gathering & processing fees — — 17,429 — 17,429 All other (1) 8,240 26,124 18,809 (36,832 ) 16,341 Total service revenue 104,406 312,718 74,484 (40,906 ) 450,702 Natural gas liquids sales — — 77,287 — 77,287 Natural gas sales 802 — 17,907 — 18,709 Crude oil sales — 6,290 515 — 6,805 Total commodity sales revenue 802 6,290 95,709 — 102,801 Total revenue from contracts with customers 105,208 319,008 170,193 (40,906 ) 553,503 Other revenue (2) — — 28,869 (9,369 ) 19,500 Total revenue (3) $ 105,208 $ 319,008 $ 199,062 $ (50,275 ) $ 573,003 (1) Includes revenue from crude oil terminal services, interruptible natural gas transportation and storage, and natural gas park and loan service. (2) Includes lease and derivative revenue not subject to ASC 606. (3) Excludes revenue recognized at unconsolidated investments, including revenue recognized at Rockies Express of $233.0 million and $696.1 million for the three and nine months ended September 30, 2019 , respectively, and $225.8 million and $683.4 million for the three and nine months ended September 30, 2018 , respectively. See Note 7 – Investments in Unconsolidated Affiliates for additional information about our investment in Rockies Express.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	We expect to recognize the total backlog during the remainder of 2019 and future periods as follows (in thousands): Year Estimated Revenue 2019 – remaining $ 126,248 2020 407,639 2021 219,345 2022 213,821 2023 176,480 Thereafter 259,331 Total $ 1,402,864
Contract with Customer, Asset and Liability	Contract balances at September 30, 2019 and December 31, 2018 were as follows: September 30, 2019 December 31, 2018 (in thousands) Accounts receivable from contracts with customers $ 83,712 $ 80,935 Other accounts receivable (1) 159,202 151,414 Receivable from related parties 3,379 3,748 Accounts receivable, net $ 246,293 $ 236,097 Deferred revenue from contracts with customers (2) $ 125,198 $ 111,095 (1) Other accounts receivable primarily consists of receivables under crude oil forward purchase and sale arrangements that are accounted for as derivatives under ASC 815. (2) Revenue recognized during the three and nine months ended September 30, 2019 that was included in the deferred revenue balance at the beginning of the period was $10.5 million and $17.0 million , respectively. This revenue primarily represented the utilization of shipper deficiencies at Pony Express.

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Lessee, Supplemental Balance Sheet	Supplemental information related to our existing leases as of September 30, 2019 was as follows: Balance Sheet Location September 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,673 (1) Current operating lease liabilities Other current liabilities $ 1,239 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,496 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 15.6 years Finance leases 39.2 years Weighted Average Discount Rate: Operating leases 5.88 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.0 million and current and non-current lease liabilities of $0.1 million and $8.9 million , respectively, related to Guernsey Terminal capacity that we lease from Powder River Gateway. (2) PLT satisfied the initial capital lease obligation of $30.7 million at lease inception and as a result has no outstanding liability or imputed interest on the future minimum rental commitments.
Lessee, Operating Lease, Liability, Maturity	Maturities of lease liabilities as of September 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 481 $ 449 2020 1,913 449 2021 1,315 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 18,961 20,015 Less: discounting for present value and other adjustments (7,226 ) (20,015 ) Present value of lease liabilities $ 11,735 $ — (1) Future lease payments for finance leases consist of the annual payments under the PLT land site lease. At lease inception, the present value of the future lease payments exceeded the fair value of the leased property. As a result, the right of use asset and capital lease obligation were recorded at the $30.7 million fair value of land. On that date, PLT made a payment of $30.7 million , immediately relieving the capital lease obligation. As a result, PLT does not have an outstanding capital lease obligation or impute interest on the future minimum rental commitments and will recognize expense for the future lease payments in the period in which they are made.
Finance Lease, Liability, Maturity	Maturities of lease liabilities as of September 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 481 $ 449 2020 1,913 449 2021 1,315 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 18,961 20,015 Less: discounting for present value and other adjustments (7,226 ) (20,015 ) Present value of lease liabilities $ 11,735 $ — (1) Future lease payments for finance leases consist of the annual payments under the PLT land site lease. At lease inception, the present value of the future lease payments exceeded the fair value of the leased property. As a result, the right of use asset and capital lease obligation were recorded at the $30.7 million fair value of land. On that date, PLT made a payment of $30.7 million , immediately relieving the capital lease obligation. As a result, PLT does not have an outstanding capital lease obligation or impute interest on the future minimum rental commitments and will recognize expense for the future lease payments in the period in which they are made.
Lessor, Operating Lease, Payments to be Received, Maturity	At September 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 2,374 2020 5,613 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 26,659
Schedule of Future Minimum Rental Payments for Operating Leases	At December 31, 2018 , our future minimum rental commitments under major, non-cancelable leases were as follows: Year Operating Leases Capital Lease (in thousands) 2019 $ 1,074 $ 449 2020 922 449 2021 483 449 2022 240 449 2023 147 449 Thereafter 364 17,770 Total $ 3,230 $ 20,015
Schedule of Future Minimum Lease Payments for Capital Leases	At December 31, 2018 , our future minimum rental commitments under major, non-cancelable leases were as follows: Year Operating Leases Capital Lease (in thousands) 2019 $ 1,074 $ 449 2020 922 449 2021 483 449 2022 240 449 2023 147 449 Thereafter 364 17,770 Total $ 3,230 $ 20,015

Net Income per Class A Share (T

Net Income per Class A Share (Tables)	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Summary of Net Income per Class A Share	The following table illustrates the calculation of net income per Class A share for the three and nine months ended September 30, 2019 and 2018 : Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (in thousands, except per unit amounts) Basic Net Income per Class A Share Net income attributable to TGE $ 72,524 $ 59,550 $ 194,730 $ 77,348 Basic weighted average Class A Shares outstanding 179,197 155,001 173,322 91,183 Basic net income per Class A share $ 0.40 $ 0.38 $ 1.12 $ 0.85 Diluted Net Income per Class A Share Net income attributable to TGE $ 72,524 $ 59,550 $ 194,730 $ 77,348 Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares 264 304 801 1,097 Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares $ 72,788 $ 59,854 $ 195,531 $ 78,445 Basic weighted average Class A Shares outstanding 179,197 155,001 173,322 91,183 Equity Participation Shares equivalent shares 958 1,087 1,434 1,478 Diluted weighted average Class A Shares outstanding 180,155 156,088 174,756 92,661 Diluted net income per Class A Share $ 0.40 $ 0.38 $ 1.12 $ 0.85

Reporting Segments (Tables)

Reporting Segments (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Summary of TGE's Segment Information of Revenue	The following tables set forth our segment information for the periods indicated: Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 32,808 $ (490 ) $ 32,318 $ 34,077 $ (816 ) $ 33,261 Crude Oil Transportation 126,787 (14,415 ) 112,372 116,250 (13,579 ) 102,671 Gathering, Processing & Terminalling 90,843 (8,824 ) 82,019 71,612 (7,224 ) 64,388 Corporate and Other — — — — — — Total revenue $ 250,438 $ (23,729 ) $ 226,709 $ 221,939 $ (21,619 ) $ 200,320 Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 103,521 $ (1,391 ) $ 102,130 $ 105,208 $ (4,136 ) $ 101,072 Crude Oil Transportation 356,741 (44,774 ) 311,967 319,008 (26,323 ) 292,685 Gathering, Processing & Terminalling 245,639 (24,151 ) 221,488 199,062 (19,816 ) 179,246 Corporate and Other — — — — — — Total revenue $ 705,901 $ (70,316 ) $ 635,585 $ 623,278 $ (50,275 ) $ 573,003
Summary of TGE's Segment Information of Earnings	Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 142,158 $ (1,163 ) $ 140,995 $ 121,433 $ (1,460 ) $ 119,973 Crude Oil Transportation 88,202 (4,527 ) 83,675 87,567 (5,008 ) 82,559 Gathering, Processing & Terminalling 35,611 5,690 41,301 13,679 6,468 20,147 Corporate and Other (2,203 ) — (2,203 ) (2,317 ) — (2,317 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 86,349 76,268 Non-cash gain related to derivative instruments (1) 1,928 2,993 Gain on disposal of assets (1) — 279 Less: Interest expense, net (1) (41,630 ) (34,019 ) Depreciation and amortization expense (1) (31,500 ) (27,356 ) Distributions from unconsolidated investments (1) (129,122 ) (100,720 ) Non-cash compensation expense (1) (2,951 ) (2,767 ) Deficiency payments, net (1) 2,329 (3,468 ) Loss on debt retirement — (2,245 ) Income tax expense (1) (22,563 ) (11,997 ) Net income attributable to Exchange Right Holders (54,084 ) (57,780 ) Net income attributable to TGE $ 72,524 $ 59,550 Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 425,286 $ (3,253 ) $ 422,033 $ 253,169 $ (2,940 ) $ 250,229 Crude Oil Transportation 258,900 (17,681 ) 241,219 150,943 (3,857 ) 147,086 Gathering, Processing & Terminalling 87,380 20,934 108,314 30,002 6,797 36,799 Corporate and Other (7,771 ) — (7,771 ) (20,819 ) — (20,819 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 273,883 153,235 Non-cash gain related to derivative instruments (1) 899 3,306 Gain on disposal of assets (1) — 3,388 Less: Interest expense, net (1) (121,941 ) (57,208 ) Depreciation and amortization expense (1) (94,819 ) (45,794 ) Distributions from unconsolidated investments (1) (369,690 ) (198,019 ) Non-cash compensation expense (1) (23,521 ) (4,738 ) Deficiency payments, net (1) (14,241 ) (7,205 ) Loss on debt retirement — (2,245 ) Income tax expense (1) (61,606 ) (35,498 ) Net income attributable to Exchange Right Holders (158,029 ) (145,169 ) Net income attributable to TGE $ 194,730 $ 77,348 (1) Net of noncontrolling interest associated with less than wholly-owned subsidiaries of Tallgrass Equity.
Summary of TGE's Segment Information of Capital Expenditures	Nine Months Ended September 30, Capital Expenditures: 2019 2018 (in thousands) Natural Gas Transportation $ 75,478 $ 96,290 Crude Oil Transportation 78,379 39,847 Gathering, Processing & Terminalling 66,411 125,866 Corporate and Other 5,194 3,070 Total capital expenditures $ 225,462 $ 265,073
Summary of TGE's Segment Information of Assets	Assets: September 30, 2019 December 31, 2018 (in thousands) Natural Gas Transportation $ 2,624,490 $ 2,606,696 Crude Oil Transportation 1,758,450 1,423,740 Gathering, Processing & Terminalling 1,580,752 1,522,559 Corporate and Other 239,205 340,514 Total assets $ 6,202,897 $ 5,893,509

Description of Business - Addit

Description of Business - Additional Information (Detail) $ / shares in Units, $ in Billions	Mar. 11, 2019USD ($)shares	Sep. 30, 2019mi	Aug. 27, 2019$ / shares	Jan. 01, 2019
Organization [Line Items]
Sale of Stock, Consideration Received on Transaction | $	$ 3.2
Proposed Sale of Stock, Price Per Share | $ / shares			$ 19.50
Rockies Express Pipeline LLC
Organization [Line Items]
Equity Method Investment, Ownership Percentage		75.00%
Powder River Gateway
Organization [Line Items]
Equity Method Investment, Ownership Percentage		51.00%
Tallgrass Energy, LP (TGE) | Powder River Gateway
Organization [Line Items]
Equity Method Investment, Ownership Percentage				51.00%
Powder River Express Pipeline
Organization [Line Items]
Miles of Pipeline | mi		70
Iron Horse Pipeline, LLC
Organization [Line Items]
Miles of Pipeline | mi		80
Tallgrass Equity, LLC | Tallgrass Energy, LP (TGE)
Organization [Line Items]
Ownership Interest		63.70%
Tallgrass Equity, LLC | Sponsor Entities
Organization [Line Items]
Partners' Capital Account, Units, Sold in Private Placement	100,655,121
Tallgrass NatGas Operator, LLC
Organization [Line Items]
Ownership Interest		100.00%
Tallgrass Terminals, LLC
Organization [Line Items]
Ownership Interest		100.00%
Tallgrass Energy, LP (TGE) | Sponsor Entities
Organization [Line Items]
Ownership Interest		44.20%
Tallgrass Energy, LP (TGE) | Common Class A | Sponsor Entities
Organization [Line Items]
Partners' Capital Account, Units, Sold in Private Placement	21,751,018
Tallgrass Energy, LP (TGE) | Common Class B | Sponsor Entities
Organization [Line Items]
Partners' Capital Account, Units, Sold in Private Placement	100,655,121
Tallgrass Energy GP, LLC | Sponsor Entities
Organization [Line Items]
Ownership Interest	100.00%	100.00%

Summary of Significant Account

Summary of Significant Account Policies (Details) - USD ($)	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Mar. 11, 2019	Jan. 01, 2019	Dec. 31, 2018
Income Tax Contingency [Line Items]
Deferred tax asset	$ 334,970,000	$ 334,970,000		$ 123,100,000		$ 273,531,000
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		14.79%	9.02%
Current Income Tax Expense (Benefit)	237,000
Operating Lease, Right-of-Use Asset	11,673,000	$ 11,673,000
Operating Lease, Liability, Current	1,239,000	1,239,000
Operating Lease, Liability, Noncurrent	$ 10,496,000	$ 10,496,000
Accounting Standards Update 2016-02
Income Tax Contingency [Line Items]
Operating Lease, Right-of-Use Asset					$ 2,300,000
Operating Lease, Liability, Current					600,000
Operating Lease, Liability, Noncurrent					$ 1,700,000
Class B Shares to Class A Shares
Income Tax Contingency [Line Items]
Conversion of Stock, Shares Converted		21,751,018

CES Acquisition - Assets Acquir

CES Acquisition - Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Thousands	May 01, 2019	Sep. 30, 2019	Sep. 30, 2019	Jun. 30, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Goodwill		$ 441,361	$ 441,361		$ 421,983
Goodwill, Purchase Accounting Adjustments			2,955
CES Holding Company, Inc.
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables	$ 1,391	1,391	1,391
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets	67	67	67
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	6,900	11,300	11,300
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment		4,400
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	35,800	32,900	32,900
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Intangibles		(2,900)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable	(1,518)	(1,518)	(1,518)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities	(8,557)	(8,746)	(8,746)
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Deferred Tax Liability		(189)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	34,083	35,394	35,394
Goodwill	17,734	16,423	16,423
Goodwill, Purchase Accounting Adjustments		(1,311)
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	$ 51,817	51,817	51,817
Finite-Lived Intangible Asset, Useful Life	8 years
Business Combination, Contingent Consideration, Liability		700	700
Adjustments
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net		1,311	1,311	$ (2,955)
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net		$ 0	$ 0	$ 0

Acquisitions - Pro Forma (Detai

Acquisitions - Pro Forma (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Business Combinations [Abstract]
Business Acquisition, Pro Forma Revenue	$ 226,709	$ 205,016	$ 640,377	$ 583,788
Business Acquisition, Pro Forma Net Income	$ 72,524	$ 60,641	$ 195,565	$ 78,695

NGL Acquisition - Assets Acquir

NGL Acquisition - Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Thousands	6 Months Ended	9 Months Ended
	Jun. 30, 2019	Sep. 30, 2019	Dec. 31, 2018	Nov. 30, 2018
Business Acquisition [Line Items]
Goodwill		$ 441,361	$ 421,983
Goodwill, Purchase Accounting Adjustments		2,955
NGL Water Solutions Bakken, LLC
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables	$ 0			$ 3,599
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Financial Assets	(3,599)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets	5			5
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	17,200			17,200
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	54,000			54,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable	305			949
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Financial Liabilities	644
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	70,900			73,855
Goodwill	20,100			17,145
Goodwill, Purchase Accounting Adjustments	2,955
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	91,000			$ 91,000
Adjustments
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	(2,955)	1,311
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	$ 0	$ 0

Acquisitions- Additional Inform

Acquisitions- Additional Information (Details) - USD ($) $ in Thousands	May 01, 2019	Jan. 01, 2019	Nov. 30, 2018	Nov. 05, 2018	Sep. 30, 2019	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Noncontrolling Interest, Increase from Business Combination							$ 31,843
Goodwill					$ 441,361			$ 441,361	$ 441,361			$ 421,983
Equity Method Investments						$ 2,113,758			122,504	$ 0
Contributions to unconsolidated investments									$ (75,179)	(444,788)
Contribution of Property		$ 86,900
Facility storage capacity				$ 20,000
BNN Eastern, LLC
Business Acquisition [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners					7.65%			7.65%	7.65%
Noncontrolling Interest, Increase from Business Combination									$ 3,400
Drexel Hamilton Infrastructure Fund I, L.P. (DHIF)
Business Acquisition [Line Items]
Right to receive special distributions				$ 35,000
Special Distribution, Current-portion									25,000
Special Distribution, Non-current portion									10,000
Powder River Gateway
Business Acquisition [Line Items]
Contributions to unconsolidated investments		$ (37,000)							$ (37,000)	$ 0
Equity Method Investment, Ownership Percentage					51.00%			51.00%	51.00%
Powder River Gateway | Tallgrass Energy, LP (TGE)
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		51.00%
Powder River Gateway | Silver Creek Midstream, LLC
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		49.00%
Iron Horse Pipeline, LLC
Business Acquisition [Line Items]
Equity Method Investments		$ 35,600
Iron Horse Pipeline, LLC | Tallgrass Energy, LP (TGE)
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		75.00%
Iron Horse Pipeline, LLC | Silver Creek Midstream, LLC
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		25.00%
CES Holding Company, Inc.
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross	$ 52,000
Business Combination, Contingent Consideration Arrangements, Range of Outcomes, Value, High	3,000
Goodwill	$ 17,734				$ 16,423			$ 16,423	$ 16,423
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual					2,400			4,500
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual					$ 800			$ 900
NGL Water Solutions Bakken, LLC
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross			$ 91,000
Goodwill			$ 17,145								$ 20,100
Business Acquisition, Percentage of Voting Interests Acquired			100.00%
Plaquemines Liquids Terminal, LLC
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired				80.00%
Preferred Membership Interest, Ownership Percentage				100.00%

Related Party Transactions - Sc

Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Revenue from affiliated companies	$ 2,020	$ 1,838	$ 5,830	$ 5,603
Related Party Costs	210	$ 0	730	$ 0
Accounts Receivable, Related Parties, Current	3,379		3,379		$ 3,748
Affiliate Gas Balance Receivables	30		30		19
Affiliate Gas Balance Payable	875		875		742
Rockies Express Pipeline LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	2,900		2,900		3,447
Powder River Gateway
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	379		379		0
Pawnee Terminal, LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	100		100		115
Iron Horse Pipeline, LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	$ 0		$ 0		$ 186

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Inventory [Line Items]
Inventories	$ 41,028	$ 34,316
Crude Oil
Inventory [Line Items]
Inventories	30,158	23,205
Materials and supplies
Inventory [Line Items]
Inventories	7,747	8,206
Gas in underground storage
Inventory [Line Items]
Inventories	2,650	2,740
Natural Gas Liquids
Inventory [Line Items]
Inventories	$ 473	$ 165

Property Plant and Equipment -

Property Plant and Equipment - Components of Property Plant and Equipment (Detail) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	$ (456,512,000)	$ (380,351,000)
Property, plant and equipment	2,865,107,000	2,802,429,000
Crude oil pipelines
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,365,353,000	1,313,976,000
Gathering, processing and terminalling assets
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	970,749,000	889,168,000
Natural gas pipelines
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	624,489,000	607,343,000
General and other (1)
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	172,708,000	180,299,000
Construction work in progress
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	188,320,000	$ 191,994,000
Plaquemines Liquids Terminal, LLC | General and other (1)
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 30,700,000

Investments in Unconsolidated_3

Investments in Unconsolidated Affiliates - Equity Method Investments (Details) - Rockies Express Pipeline LLC - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 233,010	$ 225,753	$ 696,094	$ 683,426
Equity Method Investment, Summarized Financial Information, Operating income	130,908	127,119	397,629	385,831
Equity Method Investment, Summarized Financial Information, Net Income	$ 100,968	$ 90,707	$ 322,212	$ 270,338

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Apr. 12, 2019
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated investments	$ 86,349	$ 76,268	$ 273,883	$ 222,857
Contributions to unconsolidated investments			$ (75,179)	$ (444,788)
Rockies Express Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	75.00%		75.00%
Equity in earnings of unconsolidated investments			$ 267,200
Distributions from unconsolidated investments			361,200
Contributions to unconsolidated investments			$ (49,900)
Debt Instrument, Face Amount					$ 550,000
Debt Instrument, Interest Rate, Stated Percentage					4.95%
Debt Instrument, Repurchase Amount					$ 525,000

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Goodwill [Line Items]
Goodwill	$ 441,361	$ 421,983
Goodwill, Acquired During Period	16,423
Goodwill, Purchase Accounting Adjustments	2,955
Natural Gas Transportation
Goodwill [Line Items]
Goodwill	255,558	255,558
Goodwill, Acquired During Period	0
Goodwill, Purchase Accounting Adjustments	0
Gathering, Processing & Terminalling
Goodwill [Line Items]
Goodwill	185,803	$ 166,425
Goodwill, Acquired During Period	16,423
Goodwill, Purchase Accounting Adjustments	2,955
Tallgrass Midstream, LLC
Goodwill [Line Items]
Goodwill	$ 79,200
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount	17.00%

Risk Management - Schedule of F

Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) - Energy Related Derivative $ in Thousands	Sep. 30, 2019USD ($)bbl	Dec. 31, 2018USD ($)bbl
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 4,015	$ 3,526
Derivative liability at fair value	454	1,642
Not Designated as Hedging Instrument | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 4,015	$ 3,526
Derivative, Nonmonetary Notional Amount | bbl	2,157,325	2,105,146
Not Designated as Hedging Instrument | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability at fair value	$ 454	$ 1,642
Derivative, Nonmonetary Notional Amount | bbl	4,349,000	1,274,500

Risk Management - Derivative Co

Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Not Designated as Hedging Instrument | Energy Related Derivative
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain recognized in income on derivatives	$ 14,574	$ 9,435	$ 40,631	$ 16,665

Risk Management - Derivative In

Risk Management - Derivative Instruments Maximum Potential Exposure to Credit Loss (Details) - Energy Related Derivative	Sep. 30, 2019USD ($)
Concentration Risk [Line Items]
Gross	$ 4,015,000
Netting agreement impact	0
Cash collateral held	0
Net exposure	$ 4,015,000

Risk Management - Schedule of E

Risk Management - Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification (Detail) - Energy Related Derivative - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 4,015	$ 3,526
Derivative liability at fair value	454	1,642
Quoted prices in active markets for identical assets (Level 1)
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	0	0
Derivative liability at fair value	0	0
Significant other observable inputs (Level 2)
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	4,015	3,526
Derivative liability at fair value	454	1,642
Significant unobservable inputs (Level 3)
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	0	0
Derivative liability at fair value	$ 0	$ 0

Risk Management - Additional In

Risk Management - Additional Information (Details) $ in Millions	Sep. 30, 2019USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Margin Deposit Assets	$ 0.5

Long-term Debt - Schedule of De

Long-term Debt - Schedule of Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Less: Deferred financing costs, net	$ (18,848)	$ (21,421)
Plus: Unamortized premium on 2028 Notes	3,116	3,379
Total long-term debt, net	3,451,268	3,205,958
Revolving Credit Facility
Debt Instrument [Line Items]
Long-term Debt, Gross	1,467,000	1,224,000
Total long-term debt, net	1,467,000	1,224,000
2023 Senior Notes
Debt Instrument [Line Items]
Total long-term debt, net	495,466	494,603
2023 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Long-term Debt, Gross	500,000	500,000
2024 Senior Notes
Debt Instrument [Line Items]
Total long-term debt, net	742,344	741,196
2024 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Long-term Debt, Gross	750,000	750,000
2028 Senior Notes
Debt Instrument [Line Items]
Total long-term debt, net	746,458	746,159
2028 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 750,000	$ 750,000

Long-term Debt - Capacity under

Long-term Debt - Capacity under Revolving Credit Facility (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Long-term Debt	$ (3,451,268)	$ (3,205,958)
Revolving Credit Facility
Line of Credit Facility [Line Items]
Long-term Debt	(1,467,000)	(1,224,000)
Letters of Credit Outstanding, Amount	(94)	(94)
Line of Credit Facility, Remaining Borrowing Capacity	782,906	1,025,906
Wells Fargo Bank, National Association | Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 2,250,000	$ 2,250,000

Long-term Debt - Carrying Amoun

Long-term Debt - Carrying Amount and Fair Value of Long-term Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term Debt	$ 3,451,268	$ 3,205,958
2023 Senior Notes
Debt Instrument [Line Items]
Fair Value	502,135	485,285
Long-term Debt	495,466	494,603
2023 Senior Notes | Quoted prices in active markets for identical assets (Level 1)
Debt Instrument [Line Items]
Fair Value	0	0
2023 Senior Notes | Significant other observable inputs (Level 2)
Debt Instrument [Line Items]
Fair Value	502,135	485,285
2023 Senior Notes | Significant unobservable inputs (Level 3)
Debt Instrument [Line Items]
Fair Value	0	0
2024 Senior Notes
Debt Instrument [Line Items]
Fair Value	748,305	737,745
Long-term Debt	742,344	741,196
2024 Senior Notes | Quoted prices in active markets for identical assets (Level 1)
Debt Instrument [Line Items]
Fair Value	0	0
2024 Senior Notes | Significant other observable inputs (Level 2)
Debt Instrument [Line Items]
Fair Value	748,305	737,745
2024 Senior Notes | Significant unobservable inputs (Level 3)
Debt Instrument [Line Items]
Fair Value	0	0
2028 Senior Notes
Debt Instrument [Line Items]
Fair Value	735,998	726,503
Long-term Debt	746,458	746,159
2028 Senior Notes | Quoted prices in active markets for identical assets (Level 1)
Debt Instrument [Line Items]
Fair Value	0	0
2028 Senior Notes | Significant other observable inputs (Level 2)
Debt Instrument [Line Items]
Fair Value	735,998	726,503
2028 Senior Notes | Significant unobservable inputs (Level 3)
Debt Instrument [Line Items]
Fair Value	0	0
Revolving Credit Facility
Debt Instrument [Line Items]
Fair Value	1,467,000	1,224,000
Long-term Debt	1,467,000	1,224,000
Revolving Credit Facility | Quoted prices in active markets for identical assets (Level 1)
Debt Instrument [Line Items]
Fair Value	0	0
Revolving Credit Facility | Significant other observable inputs (Level 2)
Debt Instrument [Line Items]
Fair Value	1,467,000	1,224,000
Revolving Credit Facility | Significant unobservable inputs (Level 3)
Debt Instrument [Line Items]
Fair Value	$ 0	$ 0

Long-term Debt - Additional Inf

Long-term Debt - Additional Information (Detail)	Sep. 30, 2019
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	3.54%
Debt Instrument, Interest Rate, Effective Percentage	4.35%
2023 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.75%
2024 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
2028 Senior Notes | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%

Partnership Equity - TGE Summar

Partnership Equity - TGE Summary of Dividends (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018
Equity [Abstract]
Dividends	$ 98,559	$ 96,767	$ 94,975	$ 81,304	$ 79,717	$ 77,052	$ 28,316
Dividends Payable, Amount Per Share	$ 0.5500	$ 0.5400	$ 0.5300	$ 0.5200	$ 0.5100	$ 0.4975	$ 0.4875

Partnership Equity - Additional

Partnership Equity - Additional Information (Detail) - USD ($)	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Feb. 07, 2018	Feb. 01, 2018
Limited Partners' Capital Account [Line Items]
Contributions from noncontrolling interests	$ 1,041,000		$ 1,282,000			$ 183,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ 56,390,000	$ 55,870,000	66,625,000	$ 64,019,000	$ 109,764,000	89,073,000	$ 5,200,000	$ 4,600,000
Distributions to noncontrolling interests							$ 178,885,000	262,856,000
Payments for Purchase of Common Stock								198,000,000
Units Acquired									5,619,218
Share-based Compensation Arrangement by Share-based Payment Award, Accelerated Vesting, Number							1,092,637
Share-based compensation, Shares Withheld for Taxes							543,909
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value							$ 18.82
Share-based Payment Arrangement, Accelerated Cost							$ 12,500,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period							1,796,400
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value							$ 15.19
Tallgrass Equity, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	36.30%						36.30%
Deeprock Development, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	40.00%						40.00%
BNN West Texas, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	25.00%						25.00%
BNN Colorado Water, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	37.00%						37.00%
Plaquemines Liquids Terminal, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	20.00%						20.00%
BNN Eastern, LLC
Limited Partners' Capital Account [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	7.65%						7.65%
Tallgrass Pony Express Pipeline, LLC
Limited Partners' Capital Account [Line Items]
Acquisitions						(50,000,000)		16,200,000
Carrying Value of Assets Acquired										$ 33,800,000
Rockies Express Pipeline LLC
Limited Partners' Capital Account [Line Items]
Acquisitions						108,537,000		108,500,000
Tallgrass Pony Express Pipeline, LLC
Limited Partners' Capital Account [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired										2.00%
Rockies Express Pipeline LLC
Limited Partners' Capital Account [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired									25.01%
Noncontrolling Interest
Limited Partners' Capital Account [Line Items]
Contributions from noncontrolling interests	$ 1,041,000		1,282,000			183,000	$ 2,300,000	200,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ 56,390,000	$ 55,870,000	$ 66,625,000	$ 64,019,000	$ 109,764,000	89,073,000	178,900,000	262,900,000
Distributions to noncontrolling interests							$ 173,700,000	160,600,000
Carrying Value of Common Units									$ 53,800,000
Noncontrolling Interest | Tallgrass Energy Partners, LP
Limited Partners' Capital Account [Line Items]
Distributions to noncontrolling interests								$ 97,700,000
Noncontrolling Interest | Tallgrass Pony Express Pipeline, LLC
Limited Partners' Capital Account [Line Items]
Acquisitions						(44,732,000)
Noncontrolling Interest | Rockies Express Pipeline LLC
Limited Partners' Capital Account [Line Items]
Acquisitions						$ 74,421,000
Class B Shares to Class A Shares
Limited Partners' Capital Account [Line Items]
Conversion of Stock, Shares Converted							21,751,018

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 226,709	$ 200,320	$ 635,585	$ 573,003
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	111,572	100,614	306,288	286,594
Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	29,576	30,277	93,197	92,092
Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	31,311	12,837	80,896	38,246
Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	7,021	6,631	18,431	17,429
Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,546	4,945	12,659	16,341
Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	184,026	155,304	511,471	450,702
Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	16,256	26,201	46,303	77,287
Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	8,932	5,973	24,560	18,709
Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	138	2,462	5,114	6,805
Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	25,326	34,636	75,977	102,801
Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	209,352	189,940	587,448	553,503
Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	17,357	10,380	48,137	19,500
Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	32,808	34,077	103,521	105,208
Natural Gas Transportation | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Natural Gas Transportation | Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	30,066	31,070	94,571	96,166
Natural Gas Transportation | Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Natural Gas Transportation | Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Natural Gas Transportation | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	2,742	2,551	8,831	8,240
Natural Gas Transportation | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	32,808	33,621	103,402	104,406
Natural Gas Transportation | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Natural Gas Transportation | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	456	119	802
Natural Gas Transportation | Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Natural Gas Transportation | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	456	119	802
Natural Gas Transportation | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	32,808	34,077	103,521	105,208
Natural Gas Transportation | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	126,787	116,250	356,741	319,008
Crude Oil Transportation | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	111,572	100,614	306,288	286,594
Crude Oil Transportation | Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation | Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation | Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	15,215	13,321	45,723	26,124
Crude Oil Transportation | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	126,787	113,935	352,011	312,718
Crude Oil Transportation | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Crude Oil Transportation | Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	2,315	4,730	6,290
Crude Oil Transportation | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	2,315	4,730	6,290
Crude Oil Transportation | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	126,787	116,250	356,741	319,008
Crude Oil Transportation | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Gathering, Processing & Terminalling
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	90,843	71,612	245,639	199,062
Gathering, Processing & Terminalling | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Gathering, Processing & Terminalling | Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Gathering, Processing & Terminalling | Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	31,311	12,837	80,896	38,246
Gathering, Processing & Terminalling | Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	7,021	6,631	18,431	17,429
Gathering, Processing & Terminalling | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	5,425	6,709	12,689	18,809
Gathering, Processing & Terminalling | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	43,757	26,177	112,016	74,484
Gathering, Processing & Terminalling | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	16,256	26,201	46,303	77,287
Gathering, Processing & Terminalling | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	8,932	5,517	24,441	17,907
Gathering, Processing & Terminalling | Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	138	147	384	515
Gathering, Processing & Terminalling | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	25,326	31,865	71,128	95,709
Gathering, Processing & Terminalling | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	69,083	58,042	183,144	170,193
Gathering, Processing & Terminalling | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	21,760	13,570	62,495	28,869
Corporate and Other
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(23,729)	(21,619)	(70,316)	(50,275)
Corporate and Other | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(490)	(793)	(1,374)	(4,074)
Corporate and Other | Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(18,836)	(17,636)	(54,584)	(36,832)
Corporate and Other | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(19,326)	(18,429)	(55,958)	(40,906)
Corporate and Other | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0	0	0
Corporate and Other | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(19,326)	(18,429)	(55,958)	(40,906)
Corporate and Other | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(4,403)	(3,190)	(14,358)	(9,369)
Rockies Express Pipeline LLC
Disaggregation of Revenue [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 233,010	$ 225,753	$ 696,094	$ 683,426

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Remaining Performance Obligation (Details) $ in Thousands	Sep. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
Revenue, Remaining Performance Obligation, Amount	$ 126,248
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 407,639
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 219,345
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 213,821
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 176,480
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	111 years
Revenue, Remaining Performance Obligation, Amount	$ 1,402,864

Revenue from Contracts with C_5

Revenue from Contracts with Customers - Contract with Customer, Asset and Liability (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Contract with Customer, Asset, after Allowance for Credit Loss	$ 83,712	$ 83,712	$ 80,935
Accounts and Other Receivables, Net, Current	159,202	159,202	151,414
Accounts Receivable, Related Parties, Current	3,379	3,379	3,748
Receivables, Net, Current	246,293	246,293	236,097
Deferred revenue	125,198	125,198	$ 111,095
Contract with Customer, Liability, Revenue Recognized	$ 10,500	$ 17,000

Leases - Supplemental Informati

Leases - Supplemental Information (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Nov. 05, 2018
Lessee, Lease, Description [Line Items]
Operating Lease, Right-of-Use Asset	$ 11,673
Operating Lease, Liability, Current	1,239
Operating Lease, Liability, Noncurrent	10,496
Finance Lease, Right-of-Use Asset	$ 30,704
Operating Lease, Weighted Average Remaining Lease Term	15 years 7 months 6 days
Finance Lease, Weighted Average Remaining Lease Term	39 years 2 months 12 days
Operating Lease, Weighted Average Discount Rate, Percent	5.88%
Finance Lease, Weighted Average Discount Rate, Percent	7.01%
Capital Lease Obligations		$ 30,700
Powder River Gateway
Lessee, Lease, Description [Line Items]
Operating Lease, Right-of-Use Asset	$ 9,000
Operating Lease, Liability, Current	100
Operating Lease, Liability, Noncurrent	$ 8,900

Leases, Maturity Analysis of Op

Leases, Maturity Analysis of Operating and Finance Leases (Details) - USD ($) $ in Thousands	Nov. 05, 2018	Sep. 30, 2019
Leases [Abstract]
2019 - Remaining		$ 481
2020		1,913
2021		1,315
2022		972
2023		895
Thereafter		13,385
Total Lease Payments		18,961
Less discounting for present value and other adjustments		(7,226)
Operating Lease, Liability		11,735
2019 - Remaining		449
2020		449
2021		449
2022		449
2023		449
2024		17,770
Total Lease Payments		20,015
Less discounting for present value and other adjustments		(20,015)
Finance Lease, Liability		$ 0
Capital Lease Obligations	$ 30,700
Payments to Acquire Assets, Investing Activities	$ 30,700

Lessor, Operating Leases, Payme

Lessor, Operating Leases, Payments to be Received (Details) $ in Thousands	Sep. 30, 2019USD ($)
Leases [Abstract]
2019 - Remaining	$ 2,374
2020	5,613
2021	3,773
2022	3,773
2023	3,773
Thereafter	7,353
Total	$ 26,659

Leases Schedule of Future Minim

Leases Schedule of Future Minimum Lease Payments for Operating and Capital Leases (Details) $ in Thousands	Dec. 31, 2018USD ($)
Leases [Abstract]
2019	$ 1,074
2020	922
2021	483
2022	240
2023	147
Thereafter	364
Total	3,230
2019	449
2020	449
2021	449
2022	449
2023	449
Thereafter	17,770
Total	$ 20,015

Leases - Additional Information

Leases - Additional Information (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Option to Extend		Certain of our lease agreements contain options to extend or early terminate the agreement. The lease term used to calculate the lease asset and liability at commencement includes options to extend or terminate the lease when it is reasonably certain that we will exercise that option. When determining whether it is reasonably certain that we will exercise an option at commencement, we consider various economic factors, including operating strategies, the nature, length, and underlying terms of the agreement, as well as the uncertainty of the condition of leased equipment at the end of the lease term. Based on these determinations, we generally determine that the exercise of renewal options would not be reasonably certain in determining the expected lease term.
Operating Lease, Cost	$ 0.5	$ 1
Operating Lease, Payments		0.9
Operating Lease, Lease Income, Lease Payments	$ 2.6	$ 7.3
Maximum
Lessee, Lease, Description [Line Items]
Lessee, Finance Lease, Term of Contract	39 years	39 years
Tallgrass Interstate Gas Transmission, LLC
Lessee, Lease, Description [Line Items]
Operating Lease, Lease Income, Lease Payments	$ 0.1	$ 0.5

Net Income per Class A Share (D

Net Income per Class A Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Earnings Per Share [Abstract]
Net income attributable to TGE	$ 72,524	$ 59,550	$ 194,730	$ 77,348
Basic average number of Class A shares outstanding	179,197	155,001	173,322	91,183
Basic net income per Class A share	$ 0.40	$ 0.38	$ 1.12	$ 0.85
Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares	$ 264	$ 304	$ 801	$ 1,097
Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares	$ 72,788	$ 59,854	$ 195,531	$ 78,445
Equity Participation Shares equivalent shares	958	1,087	1,434	1,478
Diluted average number of Class A shares outstanding	180,155	156,088	174,756	92,661
Diluted net income per Class A Share	$ 0.40	$ 0.38	$ 1.12	$ 0.85

Regulatory Matters (Details)

Regulatory Matters (Details) - Cheyenne Connector, LLC	Sep. 30, 2019inchmi
Regulatory Matters [Line Items]
Miles of Pipeline | mi	70
Size of Pipeline | inch	36

Legal and Environmental Matte_2

Legal and Environmental Matters - Additional Information (Detail) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2019USD ($)energy_per_duration	Dec. 31, 2018USD ($)
Loss Contingencies [Line Items]
Letters of Credit Draw	$ 16,200
Accrued taxes	28,427	$ 20,734
Environmental accruals	6,400	7,400
Total Remediation costs		$ 6,100
Insurance Recoveries	5,100
Payments for Environmental Liabilities	$ 100
Rockies Express Pipeline LLC
Loss Contingencies [Line Items]
Firm Transportation MDQ | energy_per_duration	50,000
Excise and Sales Taxes	$ 7,100
Accrued taxes	7,100
Income Taxes Receivable	14,200
EM Energy Ohio, LLC | Rockies Express Pipeline LLC
Loss Contingencies [Line Items]
Other Income	$ 13,900

Reporting Segments - Summary of

Reporting Segments - Summary of TGE's Segment Information of Revenue (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Total Revenues	$ 226,709	$ 200,320	$ 635,585	$ 573,003
TGE
Segment Reporting Information [Line Items]
Total Revenues	226,709	200,320	635,585	573,003
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	32,318	33,261	102,130	101,072
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	112,372	102,671	311,967	292,685
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	82,019	64,388	221,488	179,246
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
TGE | Operating Segments
Segment Reporting Information [Line Items]
Total Revenues	250,438	221,939	705,901	623,278
TGE | Operating Segments | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	32,808	34,077	103,521	105,208
TGE | Operating Segments | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	126,787	116,250	356,741	319,008
TGE | Operating Segments | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	90,843	71,612	245,639	199,062
TGE | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
TGE | Inter-Segment
Segment Reporting Information [Line Items]
Total Revenues	(23,729)	(21,619)	(70,316)	(50,275)
TGE | Inter-Segment | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	(490)	(816)	(1,391)	(4,136)
TGE | Inter-Segment | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	(14,415)	(13,579)	(44,774)	(26,323)
TGE | Inter-Segment | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	(8,824)	(7,224)	(24,151)	(19,816)
TGE | Inter-Segment | Corporate and Other
Segment Reporting Information [Line Items]
Total Revenues	$ 0	$ 0	$ 0	$ 0

Reporting Segments - Summary _2

Reporting Segments - Summary of TGE's Segment Information of Earnings (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Reconciliation to Net Income:
Equity in earnings of unconsolidated investments	$ (86,349)	$ (76,268)	$ (273,883)	$ (222,857)
Loss (gain) on disposal of assets	0	(279)	242	(9,417)
Depreciation and amortization	(31,797)	(27,595)	(95,778)	(81,408)
Distributions from unconsolidated investments			(274,511)	(222,082)
Share-based Payment Arrangement, Noncash Expense			(23,246)	(6,770)
Income tax expense	(22,577)	(11,997)	(61,624)	(35,498)
Net income attributable to noncontrolling interests	(55,965)	(59,162)	(162,381)	(265,378)
Net income attributable to TGE	72,524	59,550	194,730	77,348
TGE
Reconciliation to Net Income:
Net income attributable to TGE	72,524	59,550	194,730	77,348
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	140,995	119,973	422,033	250,229
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	83,675	82,559	241,219	147,086
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	41,301	20,147	108,314	36,799
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(2,203)	(2,317)	(7,771)	(20,819)
TGE | Operating Segments | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	142,158	121,433	425,286	253,169
TGE | Operating Segments | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	88,202	87,567	258,900	150,943
TGE | Operating Segments | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	35,611	13,679	87,380	30,002
TGE | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(2,203)	(2,317)	(7,771)	(20,819)
TGE | Inter-Segment | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(1,163)	(1,460)	(3,253)	(2,940)
TGE | Inter-Segment | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(4,527)	(5,008)	(17,681)	(3,857)
TGE | Inter-Segment | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	5,690	6,468	20,934	6,797
TGE | Inter-Segment | Corporate and Other
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	0	0	0	0
TGE | Segment Reconciling Items
Reconciliation to Net Income:
Equity in earnings of unconsolidated investments	86,349	76,268	273,883	(153,235)
Non-cash gain on derivative instruments	1,928	2,993	899	3,306
Loss (gain) on disposal of assets	0	279	0	3,388
Interest expense, net	(41,630)	(34,019)	(121,941)	(57,208)
Depreciation and amortization	(31,500)	(27,356)	(94,819)	(45,794)
Distributions from unconsolidated investments	(129,122)	(100,720)	(369,690)	(198,019)
Share-based Payment Arrangement, Noncash Expense	(2,951)	(2,767)	(23,521)	(4,738)
Deficiency Payments	(2,329)	3,468	14,241	7,205
Loss on debt retirement		(2,245)		(2,245)
Income tax expense	(22,563)	(11,997)	(61,606)	(35,498)
Exchange Right Holders | TGE | Segment Reconciling Items
Reconciliation to Net Income:
Net income attributable to noncontrolling interests	$ 54,084	$ 57,780	$ 158,029	$ 145,169

Reporting Segments - Summary _3

Reporting Segments - Summary of TGE's Segment Information for Payments to Acquire Plant, Property and Equipment (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Capital expenditures	$ 225,462	$ 265,073
TGE
Segment Reporting Information [Line Items]
Capital expenditures	225,462	265,073
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Capital expenditures	75,478	96,290
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Capital expenditures	78,379	39,847
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Capital expenditures	66,411	125,866
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Capital expenditures	$ 5,194	$ 3,070

Reporting Segments - Summary _4

Reporting Segments - Summary of TGE's Segment Information of Assets (Detail) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Assets	$ 6,202,897	$ 5,893,509
TGE
Segment Reporting Information [Line Items]
Assets	6,202,897	5,893,509
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Assets	2,624,490	2,606,696
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Assets	1,758,450	1,423,740
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Assets	1,580,752	1,522,559
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Assets	$ 239,205	$ 340,514

Reporting Segments - Additional

Reporting Segments - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2019Segment
Segment Reporting Information [Line Items]
Number of reportable segments	3
Rockies Express Pipeline LLC
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage	75.00%
Powder River Gateway
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage	51.00%
Pawnee Terminal, LLC
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage	51.00%

Subsequent Events (Details)

Subsequent Events (Details) - Cheyenne Connector, LLC - Subsequent Event	Oct. 28, 2019
Subsequent Event [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
DCP Midstream, LP
Subsequent Event [Line Items]
Equity Method Investment, Ownership Percentage	50.00%

Uncategorized Items - tge201993

Label	Element	Value
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 44,131,000
Noncontrolling Interest [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	39,543,000
Common Class A [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	4,588,000
Common Class B [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 0