Tallgrass Energy 10-Q 31 Jul 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Jul. 31, 2019
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 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	Q2
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	Jun. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 9,429	$ 9,596
Receivables, Net, Current	235,665	236,097
Inventories	32,669	34,316
Prepayments and other current assets	15,967	11,816
Total Current Assets	293,730	291,825
Property, plant and equipment, net	2,820,965	2,802,429
Goodwill	442,672	421,983
Intangible assets, net	253,885	227,103
Unconsolidated investments	1,998,628	1,861,686
Deferred tax asset	357,429	273,531
Deferred charges and other assets	30,685	14,952
Total Assets	6,197,994	5,893,509
Current Liabilities:
Accounts payable	181,726	201,512
Accrued taxes	21,366	20,734
Accrued interest	38,880	39,217
Accrued liabilities	15,750	23,287
Deferred revenue	127,353	111,095
Other current liabilities	40,248	42,910
Total Current Liabilities	425,323	438,755
Long-term debt, net	3,437,490	3,205,958
Other long-term liabilities and deferred credits	53,182	31,688
Total Long-term Liabilities	3,490,672	3,237,646
Commitments and Contingencies
Equity [Abstract]
Total Partners' Equity	1,870,439	1,725,537
Noncontrolling interests (a)	411,560	491,571
Total Equity	2,281,999	2,217,108
Total Liabilities and Equity	6,197,994	5,893,509
Common Class A
Equity [Abstract]
Total Partners' Equity	1,870,439	1,725,537
Common Class B
Equity [Abstract]
Total Partners' Equity	$ 0	$ 0

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Jun. 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenues:
Total Revenues	$ 211,524,000	$ 193,589,000	$ 408,876,000	$ 372,683,000
Operating Costs and Expenses:
Operations and maintenance	23,472,000	18,440,000	41,518,000	34,839,000
Depreciation and amortization	32,980,000	27,690,000	63,981,000	53,813,000
General and administrative	18,715,000	19,085,000	50,987,000	37,511,000
Taxes, other than income taxes	7,711,000	8,462,000	18,709,000	17,341,000
Loss (gain) on disposal of assets	(28,000)	(279,000)	(242,000)	9,138,000
Total Operating Costs and Expenses	121,928,000	114,314,000	248,816,000	211,495,000
Operating Income	89,596,000	79,275,000	160,060,000	161,188,000
Other Income (Expense):
Equity in earnings of unconsolidated investments	99,012,000	78,187,000	187,534,000	146,589,000
Interest expense, net	(40,595,000)	(31,282,000)	(80,300,000)	(61,043,000)
Other income, net	198,000	330,000	375,000	781,000
Total Other Income (Expense)	58,615,000	47,235,000	107,609,000	86,327,000
Net income before tax	148,211,000	126,510,000	267,669,000	247,515,000
Income tax expense	(21,981,000)	(16,809,000)	(39,047,000)	(23,501,000)
Net income	126,230,000	109,701,000	228,622,000	224,014,000
Net income attributable to noncontrolling interests	(54,611,000)	(108,638,000)	(106,416,000)	(206,216,000)
Net income attributable to TGE	$ 71,619,000	$ 1,063,000	$ 122,206,000	$ 17,798,000
Earnings Per Share, Basic and Diluted [Abstract]
Basic net income per Class A share	$ 0.40	$ 0.02	$ 0.72	$ 0.30
Diluted net income per Class A share	$ 0.40	$ 0.02	$ 0.71	$ 0.30
Basic average number of Class A shares outstanding	179,149	59,397	170,336	58,745
Diluted average number of Class A shares outstanding	180,407	59,397	171,825	58,745
Crude oil transportation services
Revenues:
Total Revenues	$ 99,456,000	$ 101,166,000	$ 194,612,000	$ 185,904,000
Natural gas transportation services
Revenues:
Total Revenues	32,345,000	31,474,000	65,861,000	63,670,000
Sales of natural gas, NGLs, and crude oil
Revenues:
Total Revenues	37,843,000	37,250,000	76,707,000	75,395,000
Processing and other revenues
Revenues:
Total Revenues	41,880,000	23,699,000	71,696,000	47,714,000
Cost of sales
Operating Costs and Expenses:
Cost of sales and transportation services	19,268,000	27,694,000	38,553,000	54,045,000
Cost of transportation services
Operating Costs and Expenses:
Cost of sales and transportation services	$ 19,754,000	$ 12,664,000	$ 34,826,000	$ 23,084,000

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	Noncontrolling Interest	Noncontrolling InterestTallgrass Energy Partners, LP	Noncontrolling InterestTallgrass Pony Express Pipeline, LLC	Noncontrolling InterestRockies Express Pipeline LLC	Common Class A	Common Class ATallgrass Energy Partners, LP	Common Class ATallgrass Pony Express Pipeline, LLC	Common Class ARockies Express Pipeline LLC	Common Class B	Common Class BTallgrass Energy Partners, LP	Common Class BTallgrass Pony Express Pipeline, LLC	Common Class BRockies Express Pipeline LLC	CES Holding Company, Inc.	CES Holding Company, Inc.Noncontrolling Interest	CES Holding Company, Inc.Common Class A	CES Holding Company, Inc.Common Class B
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	224,014,000
Distributions to noncontrolling interests	(2,900,000)				(198,800,000)
Contributions from noncontrolling interests					200,000
Acquisitions			$ 16,200,000	108,500,000
Other Significant Noncash Transaction, Value of Consideration Given	0	(2,365,501,000)		(393,039,000)
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
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	228,622,000
Distributions to noncontrolling interests	(3,900,000)				(122,500,000)
Contributions from noncontrolling interests					1,300,000
Other Significant Noncash Transaction, Value of Consideration Given	(122,504,000)	$ 0		$ 0
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

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash Flows from Operating Activities:
Net income	$ 228,622	$ 224,014
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	67,434	56,955
Equity in earnings of unconsolidated investments	(187,534)	(146,589)
Distributions from unconsolidated investments	188,043	145,581
Deferred income tax expense	38,994	23,501
Noncash compensation expense	20,570	4,003
Other noncash items, net	1,666	(10,507)
Changes in components of working capital
Accounts receivable and other	(1,777)	(93,157)
Accounts payable and accrued liabilities	(29,423)	106,592
Deferred revenue	16,294	10,711
Other current assets and liabilities	3,882	(7,631)
Other operating, net	(8,593)	2,525
Net Cash Provided by Operating Activities	330,414	331,260
Cash Flows from Investing Activities:
Capital expenditures	(150,051)	(176,275)
Contributions to unconsolidated investments	(66,084)	(22,513)
Distributions from unconsolidated investments in excess of cumulative earnings	52,525	36,502
Payments to Acquire Interest in Joint Venture		0
Sale of Tallgrass Crude Gathering	0	50,046
Other investing, net	246	(12,521)
Net Cash Used in Investing Activities	(248,780)	(269,861)
Net Cash Used in Financing Activities
Borrowings under revolving credit facilities, net	230,000	242,000
Dividends paid to Class A shareholders	(176,279)	(49,662)
Distributions to noncontrolling interests	(122,495)	(198,837)
TGE LTIP shares tendered by employees to satisfy tax withholding obligations	(13,260)	0
Other financing, net	233	(2,462)
Net Cash Used in Financing Activities	(81,801)	(58,961)
Net Change in Cash and Cash Equivalents
Net Change in Cash and Cash Equivalents	(167)	2,438
Cash and Cash Equivalents, beginning of period	9,596	2,593
Cash and Cash Equivalents, end of period	9,429	5,031
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	(122,504)	0
Accruals for property, plant and equipment	22,051	5,276
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	9,654	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)
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)
Pawnee Terminal, LLC
Cash Flows from Investing Activities:
Payments to Acquire Interest in Joint Venture	0	30,600
Deeprock North, LLC
Cash Flows from Investing Activities:
Payments to Acquire Interest in Joint Venture	0	19,500
Tallgrass Energy Partners, LP
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	0	(2,365,501)
Tallgrass Pony Express Pipeline, LLC
Net Cash Used in Financing Activities
Distributions to noncontrolling interests	0	(50,000)
Rockies Express Pipeline LLC
Supplemental Cash Flow Disclosures
Other Significant Noncash Transaction, Value of Consideration Given	0	(393,039)
Powder River Gateway
Cash Flows from Investing Activities:
Payments to Acquire Interest in Joint Venture	37,000
Common Class A
Supplemental Cash Flow Disclosures
Shares Issued	$ 0	$ 2,113,758

Description of Business

Description of Business	6 Months Ended
	Jun. 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 June 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: (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 June 30, 2019 .

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 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 six months ended June 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 six months ended June 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 six months ended June 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 six months ended June 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 8.94% for the six months ended June 30, 2018 to 14.79% for the six months ended June 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 federal income tax purposes effective May 1, 2019. As a result, we recognized approximately $53,000 of current income taxes during the three months ended June 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.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 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 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 provisional fair value of assets acquired and liabilities assumed (in thousands): Accounts receivable $ 1,391 Prepayments 67 Property, plant and equipment 6,900 Intangible asset 35,800 (1) Accounts payable and accrued liabilities (1,518 ) (2) Deferred tax liability (8,557 ) Net identifiable assets acquired 34,083 Goodwill 17,734 Net assets acquired (excluding cash) $ 51,817 (1) The $35.8 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. We are in the process of identifying and measuring all assets acquired and liabilities assumed in the acquisition within the measurement period. Such provisional amounts will be adjusted if necessary to reflect any new information about facts and circumstances that existed at the acquisition date that, if known, would have affected the measurement of these amounts. 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 $17.7 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 $2.1 million and $0.1 million , respectively, was recognized in the accompanying condensed consolidated statements of income for the period from May 1, 2019 to June 30, 2019 . Pro Forma Financial Information Unaudited pro forma revenue and net income attributable to TGE for the three and six months ended June 30, 2019 and 2018 is presented below as if the acquisition of CES had been completed on January 1, 2018. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Revenue $ 212,687 $ 197,068 $ 413,668 $ 378,772 Net income attributable to TGE $ 71,820 $ 1,230 $ 123,041 $ 18,054 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 At December 31, 2018, the assets acquired and liabilities assumed 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. 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	6 Months Ended
	Jun. 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 June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Processing and other revenues (1) $ 1,907 $ 1,869 $ 3,810 $ 3,765 Cost of transportation services (2) $ 520 $ — $ 520 $ — (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: June 30, 2019 December 31, 2018 (in thousands) Receivable from related parties: Rockies Express Pipeline LLC $ 3,280 $ 3,447 Powder River Gateway, LLC 497 — Pawnee Terminal, LLC 110 115 Iron Horse Pipeline, LLC — 186 Total receivable from related parties $ 3,887 $ 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: June 30, 2019 December 31, 2018 (in thousands) Affiliate gas imbalance receivables $ 39 $ 19 Affiliate gas imbalance payables $ 1,163 $ 742

Inventory

Inventory	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Inventory	The components of inventory at June 30, 2019 and December 31, 2018 consisted of the following: June 30, 2019 December 31, 2018 (in thousands) Crude oil $ 21,790 $ 23,205 Materials and supplies 7,667 8,206 Gas in underground storage 2,663 2,740 Natural gas liquids 549 165 Total inventory $ 32,669 $ 34,316

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	A summary of net property, plant and equipment by classification is as follows: June 30, 2019 December 31, 2018 (in thousands) Crude oil pipelines $ 1,314,055 $ 1,313,976 Gathering, processing and terminalling assets 912,812 889,168 Natural gas pipelines 621,917 607,343 General and other (1) 164,356 180,299 Construction work in progress 238,077 191,994 Accumulated depreciation and amortization (430,252 ) (380,351 ) Total property, plant and equipment, net $ 2,820,965 $ 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	6 Months Ended
	Jun. 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 six months ended June 30, 2019 , we recognized equity in earnings associated with our 75% membership interest in Rockies Express of $182.9 million , inclusive of the amortization of the negative basis difference, and received distributions from and made contributions to Rockies Express of $235.1 million and $43.6 million , respectively. Summarized financial information for Rockies Express is as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Revenue $ 232,323 $ 227,615 $ 463,084 $ 457,673 Operating income $ 134,311 $ 130,034 $ 266,721 $ 258,712 Net income to Members $ 117,635 $ 88,663 $ 221,244 $ 179,631 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 (Notes)

Goodwill (Notes)	6 Months Ended
	Jun. 30, 2019
Goodwill [Abstract]
Goodwill Disclosure [Text Block]	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 — 17,734 (1) 17,734 Other adjustments — 2,955 (2) 2,955 Balance at June 30, 2019 $ 255,558 $ 187,114 $ 442,672 (1) The $17.7 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

Risk Management	6 Months Ended
	Jun. 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 June 30, 2019 December 31, 2018 (in thousands) Crude oil derivative contracts (1) Prepayments and other current assets $ 1,843 $ 3,526 Crude oil derivative contracts (2) Other current liabilities $ 17 $ 1,642 (1) As of June 30, 2019 and December 31, 2018 , the amount shown represents the fair value of crude oil derivative contracts for the forward purchase of 1,709,914 and 2,105,146 barrels of crude oil, respectively, consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020. (2) As of June 30, 2019 and December 31, 2018 , the amount shown represents the fair value of crude oil derivative contracts for the forward sale of 1,416,008 and 1,274,500 barrels of crude oil, respectively, consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020. 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 six months ended June 30, 2019 and 2018 : Location of gain recognized Amount of gain recognized in income on derivatives Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Crude oil derivative contracts Sales of natural gas, NGLs, and crude oil $ 14,584 $ 2,935 $ 26,057 $ 7,230 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 June 30, 2019 was: Asset Position (in thousands) Gross $ 1,843 Netting agreement impact — Cash collateral held — Net exposure $ 1,843 As of June 30, 2019 , we had $1.4 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 June 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 June 30, 2019: Crude oil derivative contracts $ 1,843 $ — $ 1,843 $ — 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 June 30, 2019: Crude oil derivative contracts $ 17 $ — $ 17 $ — As of December 31, 2018: Crude oil derivative contracts $ 1,642 $ — $ 1,642 $ —

Long-term Debt

Long-term Debt	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Long-term Debt	Our long-term debt is held at TEP and consisted of the following at June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 (in thousands) Revolving credit facility $ 1,454,000 $ 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) (19,714 ) (21,421 ) Plus: Unamortized premium on 2028 Notes 3,204 3,379 Total long-term debt, net $ 3,437,490 $ 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 June 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 June 30, 2019 and December 31, 2018 : June 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 (1,454,000 ) (1,224,000 ) Less: Letters of credit issued under the revolving credit facility (94 ) (94 ) Available capacity under the revolving credit facility $ 795,906 $ 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 June 30, 2019 , TEP was in compliance with the covenants required under its revolving credit facility. As of June 30, 2019 , the weighted average interest rate on outstanding borrowings under the revolving credit facility was 3.90% . During the six months ended June 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 4.46% . 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 June 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 June 30, 2019: Revolving credit facility $ — $ 1,454,000 $ — $ 1,454,000 $ 1,454,000 2023 Notes $ — $ 508,020 $ — $ 508,020 $ 495,177 2024 Notes $ — $ 775,740 $ — $ 775,740 $ 741,954 2028 Notes $ — $ 759,075 $ — $ 759,075 $ 746,359 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 June 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 June 30, 2019 .

Partnership Equity

Partnership Equity	6 Months Ended
	Jun. 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) June 30, 2019 August 14, 2019 (1) $ 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 July 11, 2019 for the second quarter of 2019 will be paid on August 14, 2019 to Class A shareholders of record at the close of business on July 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 six months ended June 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 June 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 Water, LLC ("BNN Colorado"), a 20% common membership interest in PLT, and an approximate 8% membership interest in BNN Eastern. During the six months ended June 30, 2019 , we recognized contributions from and distributions to noncontrolling interests of $1.3 million and $122.5 million , respectively. Distributions to noncontrolling interests consisted of Tallgrass Equity distributions to the Exchange Right Holders of $118.6 million and distributions to Deeprock Development, BNN West Texas, and BNN Colorado noncontrolling interests of $3.9 million in the aggregate. During the six months ended June 30, 2018 , we recognized contributions from and made distributions to noncontrolling interests of $0.2 million and $198.8 million , respectively. Distributions to noncontrolling interests consisted of Tallgrass Equity distributions to the Exchange Right Holders of $98.2 million , distributions to TEP unitholders of $97.7 million , and distributions to Deeprock Development and Pony Express noncontrolling interests of $2.9 million in the aggregate. Other Contributions and Distributions During the six months ended June 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 six months ended June 30, 2019 . In addition, 1,775,600 Equity Participation Shares with a weighted average grant date fair value of $15.21 were granted during the six months ended June 30, 2019 .

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
	Jun. 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 June 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 $ — $ 99,439 $ — $ — $ 99,439 Natural gas transportation - firm service 31,984 — — (488 ) 31,496 Water business services — — 31,299 — 31,299 Natural gas gathering & processing fees — — 5,330 — 5,330 All other (1) 2,768 16,001 3,744 (18,714 ) 3,799 Total service revenue 34,752 115,440 40,373 (19,202 ) 171,363 Natural gas liquids sales — — 13,176 — 13,176 Natural gas sales 119 — 5,108 — 5,227 Crude oil sales — 4,730 127 — 4,857 Total commodity sales revenue 119 4,730 18,411 — 23,260 Total revenue from contracts with customers 34,871 120,170 58,784 (19,202 ) 194,623 Other revenue (2) — — 21,978 (5,077 ) 16,901 Total revenue (3) $ 34,871 $ 120,170 $ 80,762 $ (24,279 ) $ 211,524 Six Months Ended June 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 $ — $ 194,716 $ — $ — $ 194,716 Natural gas transportation - firm service 64,505 — — (884 ) 63,621 Water business services — — 49,585 — 49,585 Natural gas gathering & processing fees — — 11,410 — 11,410 All other (1) 6,089 30,508 7,264 (35,748 ) 8,113 Total service revenue 70,594 225,224 68,259 (36,632 ) 327,445 Natural gas liquids sales — — 30,047 — 30,047 Natural gas sales 119 — 15,509 — 15,628 Crude oil sales — 4,730 246 — 4,976 Total commodity sales revenue 119 4,730 45,802 — 50,651 Total revenue from contracts with customers 70,713 229,954 114,061 (36,632 ) 378,096 Other revenue (2) — — 40,735 (9,955 ) 30,780 Total revenue (3) $ 70,713 $ 229,954 $ 154,796 $ (46,587 ) $ 408,876 (1) Includes revenue from crude oil transportation walk up shippers, 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 $232.3 million and $463.1 million of revenue recognized at Rockies Express for the three and six months ended June 30, 2019 , respectively. See Note 7 – Investments in Unconsolidated Affiliates for additional information about our investment in Rockies Express. Three Months Ended June 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 $ — $ 101,242 $ — $ — $ 101,242 Natural gas transportation - firm service 31,762 — — (1,398 ) 30,364 Water business services — — 12,205 — 12,205 Natural gas gathering & processing fees — — 5,754 — 5,754 All other (1) 3,059 9,484 6,394 (13,108 ) 5,829 Total service revenue 34,821 110,726 24,353 (14,506 ) 155,394 Natural gas liquids sales — — 27,477 — 27,477 Natural gas sales 108 — 4,543 — 4,651 Crude oil sales — 2,066 121 — 2,187 Total commodity sales revenue 108 2,066 32,141 — 34,315 Total revenue from contracts with customers 34,929 112,792 56,494 (14,506 ) 189,709 Other revenue (2) — — 7,118 (3,238 ) 3,880 Total revenue (3) $ 34,929 $ 112,792 $ 63,612 $ (17,744 ) $ 193,589 Six Months Ended June 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 $ — $ 185,980 $ — $ — $ 185,980 Natural gas transportation - firm service 65,096 — — (3,281 ) 61,815 Water business services — — 25,409 — 25,409 Natural gas gathering & processing fees — — 10,798 — 10,798 All other (1) 5,689 12,803 12,100 (19,196 ) 11,396 Total service revenue 70,785 198,783 48,307 (22,477 ) 295,398 Natural gas liquids sales — — 51,086 — 51,086 Natural gas sales 346 — 12,390 — 12,736 Crude oil sales — 3,975 368 — 4,343 Total commodity sales revenue 346 3,975 63,844 — 68,165 Total revenue from contracts with customers 71,131 202,758 112,151 (22,477 ) 363,563 Other revenue (2) — — 15,299 (6,179 ) 9,120 Total revenue (3) $ 71,131 $ 202,758 $ 127,450 $ (28,656 ) $ 372,683 (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 $227.6 million and $457.7 million of revenue recognized at Rockies Express for the three and six months ended June 30, 2018 , respectively. See Note 7 – Investments in Unconsolidated Affiliates for additional information about our investment in Rockies Express. Performance Obligations On June 30, 2019 , we had $1.5 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 $ 337,924 2020 377,823 2021 178,407 2022 174,065 2023 154,302 Thereafter 243,270 Total $ 1,465,791 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, under certain water business services contracts in the Gathering, Processing & Terminalling segment. Contract balances at June 30, 2019 and December 31, 2018 were as follows: June 30, 2019 December 31, 2018 (in thousands) Accounts receivable from contracts with customers $ 83,308 $ 80,935 Other accounts receivable (1) 148,470 151,414 Receivable from related parties 3,887 3,748 Accounts receivable, net $ 235,665 $ 236,097 Deferred revenue from contracts with customers (2) $ 127,353 $ 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 six months ended June 30, 2019 that was included in the deferred revenue balance at the beginning of the period was $4.9 million and $6.5 million , respectively. This revenue primarily represented the utilization of shipper deficiencies at Pony Express.

Leases

Leases	6 Months Ended
	Jun. 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 six months ended June 30, 2019 , operating lease cost was $0.3 million and $0.5 million , respectively. For the six months ended June 30, 2019 , cash paid included in operating cash flows was $0.5 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 June 30, 2019 was as follows: Balance Sheet Location June 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,609 (1) Current operating lease liabilities Other current liabilities $ 988 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,647 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 16.0 years Finance leases 39.4 years Weighted Average Discount Rate: Operating leases 5.59 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.1 million and current and non-current lease liabilities of $0.1 million and $9.0 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 June 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 836 $ 449 2020 1,661 449 2021 1,273 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 19,022 20,015 Less: discounting for present value and other adjustments (7,387 ) (20,015 ) Present value of lease liabilities $ 11,635 $ — (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 $2.3 million and $4.7 million for the three and six months ended June 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 $0.2 million and $0.4 million for the three and six months ended June 30, 2019 , respectively, and was recorded as "Other income, net" in the condensed consolidated statements of income. At June 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 4,643 2020 4,871 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 28,186 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 six months ended June 30, 2019 , operating lease cost was $0.3 million and $0.5 million , respectively. For the six months ended June 30, 2019 , cash paid included in operating cash flows was $0.5 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 June 30, 2019 was as follows: Balance Sheet Location June 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,609 (1) Current operating lease liabilities Other current liabilities $ 988 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,647 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 16.0 years Finance leases 39.4 years Weighted Average Discount Rate: Operating leases 5.59 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.1 million and current and non-current lease liabilities of $0.1 million and $9.0 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 June 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 836 $ 449 2020 1,661 449 2021 1,273 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 19,022 20,015 Less: discounting for present value and other adjustments (7,387 ) (20,015 ) Present value of lease liabilities $ 11,635 $ — (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 $2.3 million and $4.7 million for the three and six months ended June 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 $0.2 million and $0.4 million for the three and six months ended June 30, 2019 , respectively, and was recorded as "Other income, net" in the condensed consolidated statements of income. At June 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 4,643 2020 4,871 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 28,186 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	6 Months Ended
	Jun. 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 June 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 six months ended June 30, 2019 , 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 potential issuance of TGE Equity Participation Shares would not have had a dilutive effect on the basic net income per Class A share for the three and six months ended June 30, 2018 . The following table illustrates the calculation of net income per Class A share for the three and six months ended June 30, 2019 and 2018 : Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands, except per unit amounts) Basic Net Income per Class A Share Net income attributable to TGE $ 71,619 $ 1,063 $ 122,206 $ 17,798 Basic weighted average Class A Shares outstanding 179,149 59,397 170,336 58,745 Basic net income per Class A share $ 0.40 $ 0.02 $ 0.72 $ 0.30 Diluted Net Income per Class A Share Net income attributable to TGE $ 71,619 $ 1,063 $ 122,206 $ 17,798 Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares 326 — 557 — Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares $ 71,945 $ 1,063 $ 122,763 $ 17,798 Basic weighted average Class A Shares outstanding 179,149 59,397 170,336 58,745 Equity Participation Shares equivalent shares 1,258 — 1,489 — Diluted weighted average Class A Shares outstanding 180,407 59,397 171,825 58,745 Diluted net income per Class A Share $ 0.40 $ 0.02 $ 0.71 $ 0.30

Regulatory Matters

Regulatory Matters	6 Months Ended
	Jun. 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. 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. The application is pending before the FERC. 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. The application is pending before the FERC. TIGT Pre-Filing Settlement - FERC Docket No. RP19-423-001 On May 1, 2019, TIGT filed a 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 FERC terminate the pending Form No. 501-G proceeding in Docket No. RP19-423-000 upon approval of the pre-filing settlement. The filing remains pending before the FERC. 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. The rate case remains ongoing.

Legal and Environmental Matters

Legal and Environmental Matters	6 Months Ended
	Jun. 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 June 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 possible by the end of 2019. 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 June 30, 2019 , Rockies Express has paid public utility excise taxes to the state of Ohio totaling $7.1 million and has accrued an additional $5.8 million for amounts expected to be assessed for the period from May 1, 2018 through June 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 $12.9 million asset representing the anticipated refund of the public utility excise taxes paid. 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 $6.7 million and $7.4 million at June 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	6 Months Ended
	Jun. 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. 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 June 30, 2019 Three Months Ended June 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 34,871 $ (487 ) $ 34,384 $ 34,929 $ (1,462 ) $ 33,467 Crude Oil Transportation 120,170 (15,937 ) 104,233 112,792 (9,425 ) 103,367 Gathering, Processing & Terminalling 80,762 (7,855 ) 72,907 63,612 (6,857 ) 56,755 Corporate and Other — — — — — — Total revenue $ 235,803 $ (24,279 ) $ 211,524 $ 211,333 $ (17,744 ) $ 193,589 Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 70,713 $ (901 ) $ 69,812 $ 71,131 $ (3,320 ) $ 67,811 Crude Oil Transportation 229,954 (30,359 ) 199,595 202,758 (12,744 ) 190,014 Gathering, Processing & Terminalling 154,796 (15,327 ) 139,469 127,450 (12,592 ) 114,858 Corporate and Other — — — — — — Total revenue $ 455,463 $ (46,587 ) $ 408,876 $ 401,339 $ (28,656 ) $ 372,683 Three Months Ended June 30, 2019 Three Months Ended June 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 144,260 $ (1,185 ) $ 143,075 $ 61,084 $ (745 ) $ 60,339 Crude Oil Transportation 89,957 (6,994 ) 82,963 28,505 (235 ) 28,270 Gathering, Processing & Terminalling 23,859 8,179 32,038 6,167 980 7,147 Corporate and Other (3,774 ) — (3,774 ) (6,233 ) — (6,233 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 99,012 44,554 Non-cash gain (loss) related to derivative instruments (1) 223 (559 ) Less: Interest expense, net (1) (40,601 ) (12,403 ) Depreciation and amortization expense (1) (32,591 ) (9,942 ) Distributions from unconsolidated investments (1) (125,470 ) (53,808 ) Non-cash compensation expense (1) (3,450 ) (1,009 ) Loss on disposal of assets (1) — (103 ) Deficiency payments, net (1) (4,426 ) 43 Income tax expense (1) (21,977 ) (16,809 ) Net income attributable to Exchange Right Holders (53,403 ) (38,424 ) Net income attributable to TGE $ 71,619 $ 1,063 Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 283,128 $ (2,090 ) $ 281,038 $ 131,736 $ (1,480 ) $ 130,256 Crude Oil Transportation 170,698 (13,154 ) 157,544 63,376 1,151 64,527 Gathering, Processing & Terminalling 51,769 15,244 67,013 16,323 329 16,652 Corporate and Other (5,568 ) — (5,568 ) (18,502 ) — (18,502 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 187,534 76,967 Gain on disposal of assets (1) — 3,109 Less: Interest expense, net (1) (80,311 ) (23,189 ) Depreciation and amortization expense (1) (63,319 ) (18,438 ) Distributions from unconsolidated investments (1) (240,568 ) (97,299 ) Non-cash compensation expense (1) (20,570 ) (1,971 ) Deficiency payments, net (1) (16,570 ) (3,737 ) Non-cash (loss) gain related to derivative instruments (1) (1,029 ) 313 Income tax expense (1) (39,043 ) (23,501 ) Net income attributable to Exchange Right Holders (103,945 ) (87,389 ) Net income attributable to TGE $ 122,206 $ 17,798 (1) Net of noncontrolling interest associated with less than wholly-owned subsidiaries of Tallgrass Equity. Six Months Ended June 30, Capital Expenditures: 2019 2018 (in thousands) Natural Gas Transportation $ 54,174 $ 72,882 Crude Oil Transportation 54,045 24,945 Gathering, Processing & Terminalling 38,549 76,342 Corporate and Other 3,283 2,106 Total capital expenditures $ 150,051 $ 176,275 Assets: June 30, 2019 December 31, 2018 (in thousands) Natural Gas Transportation $ 2,645,996 $ 2,606,696 Crude Oil Transportation 1,749,987 1,423,740 Gathering, Processing & Terminalling 1,541,970 1,522,559 Corporate and Other 260,041 340,514 Total assets $ 6,197,994 $ 5,893,509

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation These condensed consolidated financial statements and related notes for the three and six months ended June 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 six months ended June 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 six months ended June 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 six months ended June 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 8.94% for the six months ended June 30, 2018 to 14.79% for the six months ended June 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 federal income tax purposes effective May 1, 2019. As a result, we recognized approximately $53,000 of current income taxes during the three months ended June 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.

Leases - (Policies)

Leases - (Policies)	6 Months Ended
	Jun. 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)	6 Months Ended
	Jun. 30, 2019
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]	Unaudited pro forma revenue and net income attributable to TGE for the three and six months ended June 30, 2019 and 2018 is presented below as if the acquisition of CES had been completed on January 1, 2018. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Revenue $ 212,687 $ 197,068 $ 413,668 $ 378,772 Net income attributable to TGE $ 71,820 $ 1,230 $ 123,041 $ 18,054
CES Holding Company, Inc.
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	The following represents the provisional fair value of assets acquired and liabilities assumed (in thousands): Accounts receivable $ 1,391 Prepayments 67 Property, plant and equipment 6,900 Intangible asset 35,800 (1) Accounts payable and accrued liabilities (1,518 ) (2) Deferred tax liability (8,557 ) Net identifiable assets acquired 34,083 Goodwill 17,734 Net assets acquired (excluding cash) $ 51,817 (1) The $35.8 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 [Table Text Block]	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)	6 Months Ended
	Jun. 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 June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Processing and other revenues (1) $ 1,907 $ 1,869 $ 3,810 $ 3,765 Cost of transportation services (2) $ 520 $ — $ 520 $ — (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: June 30, 2019 December 31, 2018 (in thousands) Receivable from related parties: Rockies Express Pipeline LLC $ 3,280 $ 3,447 Powder River Gateway, LLC 497 — Pawnee Terminal, LLC 110 115 Iron Horse Pipeline, LLC — 186 Total receivable from related parties $ 3,887 $ 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: June 30, 2019 December 31, 2018 (in thousands) Affiliate gas imbalance receivables $ 39 $ 19 Affiliate gas imbalance payables $ 1,163 $ 742

Inventory - (Tables)

Inventory - (Tables)	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Schedule of Components of Inventory	The components of inventory at June 30, 2019 and December 31, 2018 consisted of the following: June 30, 2019 December 31, 2018 (in thousands) Crude oil $ 21,790 $ 23,205 Materials and supplies 7,667 8,206 Gas in underground storage 2,663 2,740 Natural gas liquids 549 165 Total inventory $ 32,669 $ 34,316

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 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: June 30, 2019 December 31, 2018 (in thousands) Crude oil pipelines $ 1,314,055 $ 1,313,976 Gathering, processing and terminalling assets 912,812 889,168 Natural gas pipelines 621,917 607,343 General and other (1) 164,356 180,299 Construction work in progress 238,077 191,994 Accumulated depreciation and amortization (430,252 ) (380,351 ) Total property, plant and equipment, net $ 2,820,965 $ 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)	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Summarized financial information for Rockies Express is as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Revenue $ 232,323 $ 227,615 $ 463,084 $ 457,673 Operating income $ 134,311 $ 130,034 $ 266,721 $ 258,712 Net income to Members $ 117,635 $ 88,663 $ 221,244 $ 179,631

Goodwill (Tables)

Goodwill (Tables)	6 Months Ended
	Jun. 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 — 17,734 (1) 17,734 Other adjustments — 2,955 (2) 2,955 Balance at June 30, 2019 $ 255,558 $ 187,114 $ 442,672 (1) The $17.7 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)	6 Months Ended
	Jun. 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 June 30, 2019 December 31, 2018 (in thousands) Crude oil derivative contracts (1) Prepayments and other current assets $ 1,843 $ 3,526 Crude oil derivative contracts (2) Other current liabilities $ 17 $ 1,642 (1) As of June 30, 2019 and December 31, 2018 , the amount shown represents the fair value of crude oil derivative contracts for the forward purchase of 1,709,914 and 2,105,146 barrels of crude oil, respectively, consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020. (2) As of June 30, 2019 and December 31, 2018 , the amount shown represents the fair value of crude oil derivative contracts for the forward sale of 1,416,008 and 1,274,500 barrels of crude oil, respectively, consisting of fixed price and floating price contracts, which will settle throughout 2019 and 2020.
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 six months ended June 30, 2019 and 2018 : Location of gain recognized Amount of gain recognized in income on derivatives Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands) Crude oil derivative contracts Sales of natural gas, NGLs, and crude oil $ 14,584 $ 2,935 $ 26,057 $ 7,230
Derivative Instruments Maximum Potential Exposure to Credit Loss	The maximum potential exposure to credit losses on our crude oil derivative contracts at June 30, 2019 was: Asset Position (in thousands) Gross $ 1,843 Netting agreement impact — Cash collateral held — Net exposure $ 1,843
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 June 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 June 30, 2019: Crude oil derivative contracts $ 1,843 $ — $ 1,843 $ — 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 June 30, 2019: Crude oil derivative contracts $ 17 $ — $ 17 $ — As of December 31, 2018: Crude oil derivative contracts $ 1,642 $ — $ 1,642 $ —

Long-term Debt (Tables)

Long-term Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Schedule of Debt	Our long-term debt is held at TEP and consisted of the following at June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 (in thousands) Revolving credit facility $ 1,454,000 $ 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) (19,714 ) (21,421 ) Plus: Unamortized premium on 2028 Notes 3,204 3,379 Total long-term debt, net $ 3,437,490 $ 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 June 30, 2019 and December 31, 2018 : June 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 (1,454,000 ) (1,224,000 ) Less: Letters of credit issued under the revolving credit facility (94 ) (94 ) Available capacity under the revolving credit facility $ 795,906 $ 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 June 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 June 30, 2019: Revolving credit facility $ — $ 1,454,000 $ — $ 1,454,000 $ 1,454,000 2023 Notes $ — $ 508,020 $ — $ 508,020 $ 495,177 2024 Notes $ — $ 775,740 $ — $ 775,740 $ 741,954 2028 Notes $ — $ 759,075 $ — $ 759,075 $ 746,359 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)	6 Months Ended
	Jun. 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) June 30, 2019 August 14, 2019 (1) $ 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 July 11, 2019 for the second quarter of 2019 will be paid on August 14, 2019 to Class A shareholders of record at the close of business on July 31, 2019 .

Revenue from Contracts with C_2

Revenue from Contracts with Customers - (Tables)	6 Months Ended
	Jun. 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 June 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 $ — $ 99,439 $ — $ — $ 99,439 Natural gas transportation - firm service 31,984 — — (488 ) 31,496 Water business services — — 31,299 — 31,299 Natural gas gathering & processing fees — — 5,330 — 5,330 All other (1) 2,768 16,001 3,744 (18,714 ) 3,799 Total service revenue 34,752 115,440 40,373 (19,202 ) 171,363 Natural gas liquids sales — — 13,176 — 13,176 Natural gas sales 119 — 5,108 — 5,227 Crude oil sales — 4,730 127 — 4,857 Total commodity sales revenue 119 4,730 18,411 — 23,260 Total revenue from contracts with customers 34,871 120,170 58,784 (19,202 ) 194,623 Other revenue (2) — — 21,978 (5,077 ) 16,901 Total revenue (3) $ 34,871 $ 120,170 $ 80,762 $ (24,279 ) $ 211,524 Six Months Ended June 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 $ — $ 194,716 $ — $ — $ 194,716 Natural gas transportation - firm service 64,505 — — (884 ) 63,621 Water business services — — 49,585 — 49,585 Natural gas gathering & processing fees — — 11,410 — 11,410 All other (1) 6,089 30,508 7,264 (35,748 ) 8,113 Total service revenue 70,594 225,224 68,259 (36,632 ) 327,445 Natural gas liquids sales — — 30,047 — 30,047 Natural gas sales 119 — 15,509 — 15,628 Crude oil sales — 4,730 246 — 4,976 Total commodity sales revenue 119 4,730 45,802 — 50,651 Total revenue from contracts with customers 70,713 229,954 114,061 (36,632 ) 378,096 Other revenue (2) — — 40,735 (9,955 ) 30,780 Total revenue (3) $ 70,713 $ 229,954 $ 154,796 $ (46,587 ) $ 408,876 (1) Includes revenue from crude oil transportation walk up shippers, 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 $232.3 million and $463.1 million of revenue recognized at Rockies Express for the three and six months ended June 30, 2019 , respectively. See Note 7 – Investments in Unconsolidated Affiliates for additional information about our investment in Rockies Express. Three Months Ended June 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 $ — $ 101,242 $ — $ — $ 101,242 Natural gas transportation - firm service 31,762 — — (1,398 ) 30,364 Water business services — — 12,205 — 12,205 Natural gas gathering & processing fees — — 5,754 — 5,754 All other (1) 3,059 9,484 6,394 (13,108 ) 5,829 Total service revenue 34,821 110,726 24,353 (14,506 ) 155,394 Natural gas liquids sales — — 27,477 — 27,477 Natural gas sales 108 — 4,543 — 4,651 Crude oil sales — 2,066 121 — 2,187 Total commodity sales revenue 108 2,066 32,141 — 34,315 Total revenue from contracts with customers 34,929 112,792 56,494 (14,506 ) 189,709 Other revenue (2) — — 7,118 (3,238 ) 3,880 Total revenue (3) $ 34,929 $ 112,792 $ 63,612 $ (17,744 ) $ 193,589 Six Months Ended June 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 $ — $ 185,980 $ — $ — $ 185,980 Natural gas transportation - firm service 65,096 — — (3,281 ) 61,815 Water business services — — 25,409 — 25,409 Natural gas gathering & processing fees — — 10,798 — 10,798 All other (1) 5,689 12,803 12,100 (19,196 ) 11,396 Total service revenue 70,785 198,783 48,307 (22,477 ) 295,398 Natural gas liquids sales — — 51,086 — 51,086 Natural gas sales 346 — 12,390 — 12,736 Crude oil sales — 3,975 368 — 4,343 Total commodity sales revenue 346 3,975 63,844 — 68,165 Total revenue from contracts with customers 71,131 202,758 112,151 (22,477 ) 363,563 Other revenue (2) — — 15,299 (6,179 ) 9,120 Total revenue (3) $ 71,131 $ 202,758 $ 127,450 $ (28,656 ) $ 372,683 (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 $227.6 million and $457.7 million of revenue recognized at Rockies Express for the three and six months ended June 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 $ 337,924 2020 377,823 2021 178,407 2022 174,065 2023 154,302 Thereafter 243,270 Total $ 1,465,791
Contract with Customer, Asset and Liability	Contract balances at June 30, 2019 and December 31, 2018 were as follows: June 30, 2019 December 31, 2018 (in thousands) Accounts receivable from contracts with customers $ 83,308 $ 80,935 Other accounts receivable (1) 148,470 151,414 Receivable from related parties 3,887 3,748 Accounts receivable, net $ 235,665 $ 236,097 Deferred revenue from contracts with customers (2) $ 127,353 $ 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 six months ended June 30, 2019 that was included in the deferred revenue balance at the beginning of the period was $4.9 million and $6.5 million , respectively. This revenue primarily represented the utilization of shipper deficiencies at Pony Express.

Leases - (Tables)

Leases - (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Lessee, Supplemental Balance Sheet	Supplemental information related to our existing leases as of June 30, 2019 was as follows: Balance Sheet Location June 30, 2019 Operating Leases: (in thousands, except lease term and discount rate) Operating lease right-of-use assets Deferred charges and other assets $ 11,609 (1) Current operating lease liabilities Other current liabilities $ 988 (1) Non-current operating lease liabilities Other long-term liabilities and deferred credits $ 10,647 (1) Finance Leases: Finance lease right-of-use asset (2) Property, plant and equipment, net $ 30,704 Weighted Average Remaining Lease Term: Operating leases 16.0 years Finance leases 39.4 years Weighted Average Discount Rate: Operating leases 5.59 % Finance leases 7.01 % (1) Includes right-of-use asset of approximately $9.1 million and current and non-current lease liabilities of $0.1 million and $9.0 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 June 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 836 $ 449 2020 1,661 449 2021 1,273 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 19,022 20,015 Less: discounting for present value and other adjustments (7,387 ) (20,015 ) Present value of lease liabilities $ 11,635 $ — (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 June 30, 2019 were as follows: Year Operating Leases Finance Leases (1) (in thousands) 2019 – remaining $ 836 $ 449 2020 1,661 449 2021 1,273 449 2022 972 449 2023 895 449 Thereafter 13,385 17,770 Total lease payments 19,022 20,015 Less: discounting for present value and other adjustments (7,387 ) (20,015 ) Present value of lease liabilities $ 11,635 $ — (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 June 30, 2019 , future minimum rental income under non-cancelable operating leases as the lessor were as follows: Year Total (in thousands) 2019 - remaining $ 4,643 2020 4,871 2021 3,773 2022 3,773 2023 3,773 Thereafter 7,353 Total $ 28,186
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)	6 Months Ended
	Jun. 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 six months ended June 30, 2019 and 2018 : Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (in thousands, except per unit amounts) Basic Net Income per Class A Share Net income attributable to TGE $ 71,619 $ 1,063 $ 122,206 $ 17,798 Basic weighted average Class A Shares outstanding 179,149 59,397 170,336 58,745 Basic net income per Class A share $ 0.40 $ 0.02 $ 0.72 $ 0.30 Diluted Net Income per Class A Share Net income attributable to TGE $ 71,619 $ 1,063 $ 122,206 $ 17,798 Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares 326 — 557 — Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares $ 71,945 $ 1,063 $ 122,763 $ 17,798 Basic weighted average Class A Shares outstanding 179,149 59,397 170,336 58,745 Equity Participation Shares equivalent shares 1,258 — 1,489 — Diluted weighted average Class A Shares outstanding 180,407 59,397 171,825 58,745 Diluted net income per Class A Share $ 0.40 $ 0.02 $ 0.71 $ 0.30

Reporting Segments (Tables)

Reporting Segments (Tables)	6 Months Ended
	Jun. 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 June 30, 2019 Three Months Ended June 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 34,871 $ (487 ) $ 34,384 $ 34,929 $ (1,462 ) $ 33,467 Crude Oil Transportation 120,170 (15,937 ) 104,233 112,792 (9,425 ) 103,367 Gathering, Processing & Terminalling 80,762 (7,855 ) 72,907 63,612 (6,857 ) 56,755 Corporate and Other — — — — — — Total revenue $ 235,803 $ (24,279 ) $ 211,524 $ 211,333 $ (17,744 ) $ 193,589 Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 Revenue: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 70,713 $ (901 ) $ 69,812 $ 71,131 $ (3,320 ) $ 67,811 Crude Oil Transportation 229,954 (30,359 ) 199,595 202,758 (12,744 ) 190,014 Gathering, Processing & Terminalling 154,796 (15,327 ) 139,469 127,450 (12,592 ) 114,858 Corporate and Other — — — — — — Total revenue $ 455,463 $ (46,587 ) $ 408,876 $ 401,339 $ (28,656 ) $ 372,683
Summary of TGE's Segment Information of Earnings	Three Months Ended June 30, 2019 Three Months Ended June 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 144,260 $ (1,185 ) $ 143,075 $ 61,084 $ (745 ) $ 60,339 Crude Oil Transportation 89,957 (6,994 ) 82,963 28,505 (235 ) 28,270 Gathering, Processing & Terminalling 23,859 8,179 32,038 6,167 980 7,147 Corporate and Other (3,774 ) — (3,774 ) (6,233 ) — (6,233 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 99,012 44,554 Non-cash gain (loss) related to derivative instruments (1) 223 (559 ) Less: Interest expense, net (1) (40,601 ) (12,403 ) Depreciation and amortization expense (1) (32,591 ) (9,942 ) Distributions from unconsolidated investments (1) (125,470 ) (53,808 ) Non-cash compensation expense (1) (3,450 ) (1,009 ) Loss on disposal of assets (1) — (103 ) Deficiency payments, net (1) (4,426 ) 43 Income tax expense (1) (21,977 ) (16,809 ) Net income attributable to Exchange Right Holders (53,403 ) (38,424 ) Net income attributable to TGE $ 71,619 $ 1,063 Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 Tallgrass Equity Adjusted EBITDA: Total Inter- External Total Inter- External (in thousands) Natural Gas Transportation $ 283,128 $ (2,090 ) $ 281,038 $ 131,736 $ (1,480 ) $ 130,256 Crude Oil Transportation 170,698 (13,154 ) 157,544 63,376 1,151 64,527 Gathering, Processing & Terminalling 51,769 15,244 67,013 16,323 329 16,652 Corporate and Other (5,568 ) — (5,568 ) (18,502 ) — (18,502 ) Reconciliation to Net Income: Add: Equity in earnings of unconsolidated investments (1) 187,534 76,967 Gain on disposal of assets (1) — 3,109 Less: Interest expense, net (1) (80,311 ) (23,189 ) Depreciation and amortization expense (1) (63,319 ) (18,438 ) Distributions from unconsolidated investments (1) (240,568 ) (97,299 ) Non-cash compensation expense (1) (20,570 ) (1,971 ) Deficiency payments, net (1) (16,570 ) (3,737 ) Non-cash (loss) gain related to derivative instruments (1) (1,029 ) 313 Income tax expense (1) (39,043 ) (23,501 ) Net income attributable to Exchange Right Holders (103,945 ) (87,389 ) Net income attributable to TGE $ 122,206 $ 17,798 (1) Net of noncontrolling interest associated with less than wholly-owned subsidiaries of Tallgrass Equity.
Summary of TGE's Segment Information of Capital Expenditures	Six Months Ended June 30, Capital Expenditures: 2019 2018 (in thousands) Natural Gas Transportation $ 54,174 $ 72,882 Crude Oil Transportation 54,045 24,945 Gathering, Processing & Terminalling 38,549 76,342 Corporate and Other 3,283 2,106 Total capital expenditures $ 150,051 $ 176,275
Summary of TGE's Segment Information of Assets	Assets: June 30, 2019 December 31, 2018 (in thousands) Natural Gas Transportation $ 2,645,996 $ 2,606,696 Crude Oil Transportation 1,749,987 1,423,740 Gathering, Processing & Terminalling 1,541,970 1,522,559 Corporate and Other 260,041 340,514 Total assets $ 6,197,994 $ 5,893,509

Description of Business - Addit

Description of Business - Additional Information (Detail) $ in Billions	Mar. 11, 2019USD ($)shares	Jun. 30, 2019mi	Jan. 01, 2019
Organization [Line Items]
Sale of Stock, Consideration Received on Transaction | $	$ 3.2
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 Accoun_3

Summary of Significant Accounting Policies Summary of Significant Account Policies (Details) - USD ($)	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Jun. 30, 2018	Mar. 11, 2019	Jan. 01, 2019	Dec. 31, 2018
Income Tax Contingency [Line Items]
Deferred tax asset	$ 357,429,000	$ 357,429,000		$ 123,100,000		$ 273,531,000
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		14.79%	8.94%
Current Income Tax Expense (Benefit)	53,000
Operating Lease, Right-of-Use Asset	11,609,000	$ 11,609,000
Operating Lease, Liability, Current	988,000	988,000
Operating Lease, Liability, Noncurrent	$ 10,647,000	$ 10,647,000
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

Acquisitions - Assets Acquired

Acquisitions - Assets Acquired And Liabilities Assumed (Details) - USD ($) $ in Thousands	May 01, 2019	Jun. 30, 2019	Dec. 31, 2018	Nov. 30, 2018
Business Acquisition [Line Items]
Goodwill		$ 442,672	$ 421,983
CES Holding Company, Inc.
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables	$ 1,391
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets	67
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	6,900
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	35,800
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable	(1,518)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities	8,557
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	34,083
Goodwill	17,734
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net	$ 51,817
Finite-Lived Intangible Asset, Useful Life	8 years
Business Combination, Contingent Consideration, Liability	$ 700
Preliminary
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				$ 3,599
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets				5
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				17,200
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill				54,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				(949)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				73,855
Goodwill				17,145
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net				91,000
Adjustments
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				(3,599)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets				0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill				0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				(644)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				(2,955)
Goodwill				2,955
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net				0
NGL Water Solutions Bakken, LLC
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets				5
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				17,200
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill				54,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				(305)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				70,900
Goodwill				20,100
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net				$ 91,000

Acquisitions - Pro Forma (Detai

Acquisitions - Pro Forma (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Business Combinations [Abstract]
Business Acquisition, Pro Forma Revenue	$ 212,687	$ 197,068	$ 413,668	$ 378,772
Business Acquisition, Pro Forma Net Income (Loss)	$ 71,820	$ 1,230	$ 123,041	$ 18,054

Acquisitions- Additional Inform

Acquisitions- Additional Information (Details) - USD ($) $ in Thousands	May 01, 2019	Jan. 01, 2019	Nov. 30, 2018	Nov. 05, 2018	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Business Acquisition [Line Items]
Noncontrolling Interest, Increase from Business Combination							$ 31,843
Goodwill					$ 442,672			$ 442,672		$ 421,983
Equity Method Investments						$ 2,113,758		122,504	$ 0
Contributions to unconsolidated investments								$ (66,084)	$ (22,513)
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%
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]
Equity Method Investment, Ownership Percentage					51.00%			51.00%
Contributions to unconsolidated investments		$ (37,000)
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
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual					$ 2,100
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual					$ 100
NGL Water Solutions Bakken, LLC
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross			$ 91,000
Goodwill			$ 20,100
Business Acquisition, Percentage of Voting Interests Acquired			100.00%
Plaquemines Liquids Terminal, LLC
Business Acquisition [Line Items]
Preferred Membership Interest, Ownership Percentage				100.00%
Business Acquisition, Percentage of Voting Interests Acquired				80.00%

Related Party Transactions - Sc

Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Revenue from affiliated companies	$ 1,907	$ 1,869	$ 3,810	$ 3,765
Related Party Costs	520	$ 0	520	$ 0
Accounts Receivable, Related Parties, Current	3,887		3,887		$ 3,748
Affiliate Gas Balance Receivables	39		39		19
Affiliate Gas Balance Payable	1,163		1,163		742
Rockies Express Pipeline LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	3,280		3,280		3,447
Powder River Gateway
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	497		497		0
Pawnee Terminal, LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	110		110		115
Iron Horse Pipeline, LLC
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	$ 0		$ 0		$ 186

Inventory Inventory (Details)

Inventory Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Inventory [Line Items]
Inventories	$ 32,669	$ 34,316
Crude Oil
Inventory [Line Items]
Inventories	21,790	23,205
Materials and supplies
Inventory [Line Items]
Inventories	7,667	8,206
Gas in underground storage
Inventory [Line Items]
Inventories	2,663	2,740
Natural Gas Liquids
Inventory [Line Items]
Inventories	$ 549	$ 165

Property Plant and Equipment -

Property Plant and Equipment - Components of Property Plant and Equipment (Detail) - USD ($)	Jun. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	$ (430,252,000)	$ (380,351,000)
Property, plant and equipment	2,820,965,000	2,802,429,000
Crude oil pipelines
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,314,055,000	1,313,976,000
Gathering, processing and terminalling assets
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	912,812,000	889,168,000
Natural gas pipelines
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	621,917,000	607,343,000
General and other (1)
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	164,356,000	180,299,000
Construction work in progress
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	238,077,000	$ 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 232,323	$ 227,615	$ 463,084	$ 457,673
Equity Method Investment, Summarized Financial Information, Operating income	134,311	130,034	266,721	258,712
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	$ 117,635	$ 88,663	$ 221,244	$ 179,631

Investments in Unconsolidated_4

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Apr. 12, 2019
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated investments	$ 99,012	$ 78,187	$ 187,534	$ 146,589
Contributions to unconsolidated investments			$ (66,084)	$ (22,513)
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			$ 182,900
Distributions from unconsolidated investments			235,100
Contributions to unconsolidated investments			$ (43,600)
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	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Goodwill [Line Items]
Goodwill	$ 442,672	$ 421,983
Goodwill, Acquired During Period	17,734
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	187,114	$ 166,425
Goodwill, Acquired During Period	17,734
Goodwill, Purchase Accounting Adjustments	$ 2,955

Risk Management - Schedule of F

Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) - Energy Related Derivative $ in Thousands	Jun. 30, 2019USD ($)bbl	Dec. 31, 2018USD ($)bbl
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 1,843	$ 3,526
Derivative liability at fair value	17	1,642
Not Designated as Hedging Instrument | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 1,843	$ 3,526
Derivative, Nonmonetary Notional Amount | bbl	1,709,914	2,105,146
Not Designated as Hedging Instrument | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability at fair value	$ 17	$ 1,642
Derivative, Nonmonetary Notional Amount | bbl	1,416,008	1,274,500

Risk Management - Derivative Co

Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Not Designated as Hedging Instrument | Energy Related Derivative
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain recognized in income on derivatives	$ 14,584	$ 2,935	$ 26,057	$ 7,230

Risk Management - Derivative In

Risk Management - Derivative Instruments Maximum Potential Exposure to Credit Loss (Details) - Energy Related Derivative	Jun. 30, 2019USD ($)
Concentration Risk [Line Items]
Gross	$ 1,843,000
Netting agreement impact	0
Cash collateral held	0
Net exposure	$ 1,843,000

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	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative asset at fair value	$ 1,843	$ 3,526
Derivative liability at fair value	17	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	1,843	3,526
Derivative liability at fair value	17	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 Risk Management

Risk Management Risk Management - Additional Information (Details) $ in Millions	Jun. 30, 2019USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Margin Deposit Assets	$ 1.4

Long-term Debt - Schedule of De

Long-term Debt - Schedule of Debt (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Less: Deferred financing costs, net	$ (19,714)	$ (21,421)
Plus: Unamortized premium on 2028 Notes	3,204	3,379
Total long-term debt, net	3,437,490	3,205,958
Revolving Credit Facility
Debt Instrument [Line Items]
Long-term Debt, Gross	1,454,000	1,224,000
Total long-term debt, net	1,454,000	1,224,000
2023 Senior Notes
Debt Instrument [Line Items]
Total long-term debt, net	495,177	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	741,954	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	746,359	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	Jun. 30, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Long-term Debt	$ (3,437,490)	$ (3,205,958)
Revolving Credit Facility
Line of Credit Facility [Line Items]
Long-term Debt	(1,454,000)	(1,224,000)
Letters of Credit Outstanding, Amount	(94)	(94)
Line of Credit Facility, Remaining Borrowing Capacity	795,906	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	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term Debt	$ 3,437,490	$ 3,205,958
2023 Senior Notes
Debt Instrument [Line Items]
Fair Value	508,020	485,285
Long-term Debt	495,177	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	508,020	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	775,740	737,745
Long-term Debt	741,954	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	775,740	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	759,075	726,503
Long-term Debt	746,359	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	759,075	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	1,454,000	1,224,000
Long-term Debt	1,454,000	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	1,454,000	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)	Jun. 30, 2019
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	3.90%
Debt Instrument, Interest Rate, Effective Percentage	4.46%
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
	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018
Equity [Abstract]
Dividends	$ 96,767	$ 94,975	$ 81,304	$ 79,717	$ 77,052	$ 28,316
Dividends Payable, Amount Per Share	$ 0.5400	$ 0.5300	$ 0.5200	$ 0.5100	$ 0.4975	$ 0.4875

Partnership Equity - Additional

Partnership Equity - Additional Information (Detail) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Feb. 07, 2018	Feb. 01, 2018
Limited Partners' Capital Account [Line Items]
Contributions from noncontrolling interests		$ 1,282,000		$ 183,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ 55,870,000	66,625,000	$ 109,764,000	89,073,000	$ 3,900,000	$ 2,900,000
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					1,775,600
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value					$ 15.21
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		1,282,000		183,000	$ 1,300,000	200,000
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ 55,870,000	$ 66,625,000	$ 109,764,000	89,073,000	122,500,000	198,800,000
Distributions to noncontrolling interests					$ 118,600,000	98,200,000
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 211,524	$ 193,589	$ 408,876	$ 372,683
Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	99,439	101,242	194,716	185,980
Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	31,496	30,364	63,621	61,815
Water business services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	31,299	12,205	49,585	25,409
Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	5,330	5,754	11,410	10,798
Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3,799	5,829	8,113	11,396
Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	171,363	155,394	327,445	295,398
Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	13,176	27,477	30,047	51,086
Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	5,227	4,651	15,628	12,736
Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,857	2,187	4,976	4,343
Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	23,260	34,315	50,651	68,165
Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	194,623	189,709	378,096	363,563
Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	16,901	3,880	30,780	9,120
Natural Gas Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	34,871	34,929	70,713	71,131
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	31,984	31,762	64,505	65,096
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	2,768	3,059	6,089	5,689
Natural Gas Transportation | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	34,752	34,821	70,594	70,785
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	119	108	119	346
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	119	108	119	346
Natural Gas Transportation | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	34,871	34,929	70,713	71,131
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	120,170	112,792	229,954	202,758
Crude Oil Transportation | Crude Oil Transportation
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	99,439	101,242	194,716	185,980
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	16,001	9,484	30,508	12,803
Crude Oil Transportation | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	115,440	110,726	225,224	198,783
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	4,730	2,066	4,730	3,975
Crude Oil Transportation | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,730	2,066	4,730	3,975
Crude Oil Transportation | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	120,170	112,792	229,954	202,758
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	80,762	63,612	154,796	127,450
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	31,299	12,205	49,585	25,409
Gathering, Processing & Terminalling | Natural Gas Gathering & Processing
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	5,330	5,754	11,410	10,798
Gathering, Processing & Terminalling | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3,744	6,394	7,264	12,100
Gathering, Processing & Terminalling | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	40,373	24,353	68,259	48,307
Gathering, Processing & Terminalling | Natural Gas Liquids
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	13,176	27,477	30,047	51,086
Gathering, Processing & Terminalling | Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	5,108	4,543	15,509	12,390
Gathering, Processing & Terminalling | Crude Oil
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	127	121	246	368
Gathering, Processing & Terminalling | Energy Commodities and Service
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	18,411	32,141	45,802	63,844
Gathering, Processing & Terminalling | Total Service and Commodity Sales Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	58,784	56,494	114,061	112,151
Gathering, Processing & Terminalling | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	21,978	7,118	40,735	15,299
Corporate and Other
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(24,279)	(17,744)	(46,587)	(28,656)
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	(488)	(1,398)	(884)	(3,281)
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	(18,714)	(13,108)	(35,748)	(19,196)
Corporate and Other | Service Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(19,202)	(14,506)	(36,632)	(22,477)
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	(19,202)	(14,506)	(36,632)	(22,477)
Corporate and Other | Other Revenue
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(5,077)	(3,238)	(9,955)	(6,179)
Rockies Express Pipeline LLC
Disaggregation of Revenue [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 232,323	$ 227,615	$ 463,084	$ 457,673

Revenue from Contract with Cust

Revenue from Contract with Customer - Remaining Performance Obligation (Details) $ in Thousands	Jun. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Revenue, Remaining Performance Obligation, Amount	$ 337,924
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	$ 377,823
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	$ 178,407
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	$ 174,065
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	$ 154,302
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	$ 1,465,791

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Contract with Customer, Asset and Liability (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Contract with Customer, Asset, after Allowance for Credit Loss	$ 83,308	$ 83,308	$ 80,935
Accounts and Other Receivables, Net, Current	148,470	148,470	151,414
Accounts Receivable, Related Parties, Current	3,887	3,887	3,748
Receivables, Net, Current	235,665	235,665	236,097
Deferred revenue	127,353	127,353	$ 111,095
Contract with Customer, Liability, Revenue Recognized	$ 4,900	$ 6,500

Leases Leases - Supplemental In

Leases Leases - Supplemental Information (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Nov. 05, 2018
Lessee, Lease, Description [Line Items]
Operating Lease, Right-of-Use Asset	$ 11,609
Operating Lease, Liability, Current	988
Operating Lease, Liability, Noncurrent	10,647
Finance Lease, Right-of-Use Asset	$ 30,704
Operating Lease, Weighted Average Remaining Lease Term	16 years
Finance Lease, Weighted Average Remaining Lease Term	39 years 4 months 24 days
Finance Lease, Weighted Average Discount Rate, Percent	7.01%
Operating Lease, Weighted Average Discount Rate, Percent	5.59%
Capital Lease Obligations		$ 30,700
Powder River Gateway
Lessee, Lease, Description [Line Items]
Operating Lease, Right-of-Use Asset	$ 9,100
Operating Lease, Liability, Current	100
Operating Lease, Liability, Noncurrent	$ 9,000

Leases, Maturity Analysis of Op

Leases, Maturity Analysis of Operating and Finance Leases (Details) - USD ($) $ in Thousands	Nov. 05, 2018	Jun. 30, 2019
Leases [Abstract]
2019 - Remaining		$ 836
2020		1,661
2021		1,273
2022		972
2023		895
Thereafter		13,385
Total Lease Payments		19,022
Less discounting for present value and other adjustments		(7,387)
Operating Lease, Liability		11,635
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	Jun. 30, 2019USD ($)
Leases [Abstract]
2019 - Remaining	$ 4,643
2020	4,871
2021	3,773
2022	3,773
2023	3,773
Thereafter	7,353
Total	$ 28,186

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	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)
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	$ 0.3	$ 0.5
Operating Lease, Payments		0.5
Operating Lease, Lease Income, Lease Payments	$ 2.3	$ 4.7
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	$ 0.2	$ 0.4

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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Net income attributable to TGE	$ 71,619	$ 1,063	$ 122,206	$ 17,798
Basic average number of Class A shares outstanding	179,149	59,397	170,336	58,745
Basic net income per Class A share	$ 0.40	$ 0.02	$ 0.72	$ 0.30
Incremental net income attributable to TGE including the effect of the assumed issuance of Equity Participation Shares	$ 326	$ 0	$ 557	$ 0
Net income attributable to TGE including incremental net income from assumed issuance of Equity Participation Shares	$ 71,945	$ 1,063	$ 122,763	$ 17,798
Equity Participation Shares equivalent shares	1,258	0	1,489	0
Diluted average number of Class A shares outstanding	180,407	59,397	171,825	58,745
Diluted net income per Class A Share	$ 0.40	$ 0.02	$ 0.71	$ 0.30

Regulatory Matters (Details)

Regulatory Matters (Details) - Cheyenne Connector, LLC	Jun. 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	6 Months Ended	12 Months Ended
	Jun. 30, 2019USD ($)energy_per_duration	Dec. 31, 2018USD ($)
Loss Contingencies [Line Items]
Letters of Credit Draw	$ 16,200
Accrued taxes	21,366	$ 20,734
Environmental accruals	6,700	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	5,800
Income Taxes Receivable	12,900
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Segment Reporting Information [Line Items]
Total Revenues	$ 211,524	$ 193,589	$ 408,876	$ 372,683
TGE
Segment Reporting Information [Line Items]
Total Revenues	211,524	193,589	408,876	372,683
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	34,384	33,467	69,812	67,811
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	104,233	103,367	199,595	190,014
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	72,907	56,755	139,469	114,858
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	235,803	211,333	455,463	401,339
TGE | Operating Segments | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	34,871	34,929	70,713	71,131
TGE | Operating Segments | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	120,170	112,792	229,954	202,758
TGE | Operating Segments | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	80,762	63,612	154,796	127,450
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	(24,279)	(17,744)	(46,587)	(28,656)
TGE | Inter-Segment | Natural Gas Transportation
Segment Reporting Information [Line Items]
Total Revenues	(487)	(1,462)	(901)	(3,320)
TGE | Inter-Segment | Crude Oil Transportation
Segment Reporting Information [Line Items]
Total Revenues	(15,937)	(9,425)	(30,359)	(12,744)
TGE | Inter-Segment | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Total Revenues	(7,855)	(6,857)	(15,327)	(12,592)
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Reconciliation to Net Income:
Equity in earnings of unconsolidated investments	$ (99,012)	$ (78,187)	$ (187,534)	$ (146,589)
Depreciation and amortization	(32,980)	(27,690)	(63,981)	(53,813)
Distributions from unconsolidated investments			(188,043)	(145,581)
Share-based Payment Arrangement, Noncash Expense			(20,570)	(4,003)
Loss (gain) on disposal of assets	28	279	242	(9,138)
Income tax expense	(21,981)	(16,809)	(39,047)	(23,501)
Net income attributable to noncontrolling interests	(54,611)	(108,638)	(106,416)	(206,216)
Net income attributable to TGE	71,619	1,063	122,206	17,798
TGE
Reconciliation to Net Income:
Net income attributable to TGE	71,619	1,063	122,206	17,798
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	143,075	60,339	281,038	130,256
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	82,963	28,270	157,544	64,527
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	32,038	7,147	67,013	16,652
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(3,774)	(6,233)	(5,568)	(18,502)
TGE | Operating Segments | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	144,260	61,084	283,128	131,736
TGE | Operating Segments | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	89,957	28,505	170,698	63,376
TGE | Operating Segments | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	23,859	6,167	51,769	16,323
TGE | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(3,774)	(6,233)	(5,568)	(18,502)
TGE | Inter-Segment | Natural Gas Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(1,185)	(745)	(2,090)	(1,480)
TGE | Inter-Segment | Crude Oil Transportation
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	(6,994)	(235)	(13,154)	1,151
TGE | Inter-Segment | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Adjusted Earnings Before Interest Taxes Depreciation And Amortization	8,179	980	15,244	329
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	99,012	44,554	187,534	(76,967)
Non-cash gain (loss) on derivative instruments	223	(559)	(1,029)	313
Interest expense, net	(40,601)	(12,403)	(80,311)	(23,189)
Depreciation and amortization	(32,591)	(9,942)	(63,319)	(18,438)
Distributions from unconsolidated investments	(125,470)	(53,808)	(240,568)	(97,299)
Share-based Payment Arrangement, Noncash Expense	(3,450)	(1,009)	(20,570)	(1,971)
Loss (gain) on disposal of assets	0	(103)	0	3,109
Deficiency Payments	4,426	(43)	16,570	3,737
Income tax expense	(21,977)	(16,809)	(39,043)	(23,501)
Exchange Right Holders | TGE | Segment Reconciling Items
Reconciliation to Net Income:
Net income attributable to noncontrolling interests	$ 53,403	$ 38,424	$ 103,945	$ 87,389

Reporting Segments - Summary _3

Reporting Segments - Summary of TGE's Segment Information for Payments to Acquire Plant, Property and Equipment (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Segment Reporting Information [Line Items]
Capital expenditures	$ 150,051	$ 176,275
TGE
Segment Reporting Information [Line Items]
Capital expenditures	150,051	176,275
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Capital expenditures	54,174	72,882
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Capital expenditures	54,045	24,945
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Capital expenditures	38,549	76,342
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Capital expenditures	$ 3,283	$ 2,106

Reporting Segments - Summary _4

Reporting Segments - Summary of TGE's Segment Information of Assets (Detail) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Assets	$ 6,197,994	$ 5,893,509
TGE
Segment Reporting Information [Line Items]
Assets	6,197,994	5,893,509
TGE | Natural Gas Transportation
Segment Reporting Information [Line Items]
Assets	2,645,996	2,606,696
TGE | Crude Oil Transportation
Segment Reporting Information [Line Items]
Assets	1,749,987	1,423,740
TGE | Gathering, Processing & Terminalling
Segment Reporting Information [Line Items]
Assets	1,541,970	1,522,559
TGE | Corporate and Other
Segment Reporting Information [Line Items]
Assets	$ 260,041	$ 340,514

Reporting Segments - Additional

Reporting Segments - Additional Information (Detail)	6 Months Ended
	Jun. 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%

Uncategorized Items - tge201963

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 B [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	0
Common Class A [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 4,588,000