Tallgrass Energy Partners 10-Q 6 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014	Aug. 01, 2014	Aug. 01, 2014
		Common Units [Member]	Subordinated Units [Member]	General Partner Units [Member]
Document Information [Line Items]	'	'	'	'
Document Type	'10-Q	'	'	'
Amendment Flag	'false	'	'	'
Document Period End Date	30-Jun-14	'	'	'
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q2	'	'	'
Trading Symbol	'TEP	'	'	'
Entity Registrant Name	'TALLGRASS ENERGY PARTNERS, LP	'	'	'
Entity Central Index Key	'0001569134	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'
Entity Filer Category	'Non-accelerated Filer	'	'	'
Entity Common Stock, Shares Outstanding	'	32,735,140	16,200,000	834,391

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$16	$0
Accounts receivable, net	27,698	30,033
Gas imbalances	1,336	3,128
Inventories	8,122	5,549
Prepayments and other current assets	1,788	16,986
Total Current Assets	38,960	55,696
Property, plant and equipment, net	660,251	657,780
Goodwill	343,288	334,715
Intangible asset, net	7,495	0
Unconsolidated investment	0	1,255
Deferred financing costs	6,273	4,512
Deferred charges and other assets	11,048	11,299
Total Assets	1,067,315	1,065,257
Current Liabilities:	'	'
Accounts payable	27,940	60,240
Accounts payable to related parties	3,963	7,137
Gas imbalances	4,407	3,664
Derivative liabilities at fair value	439	184
Accrued taxes	3,871	5,520
Accrued other current liabilities	16,988	16,748
Total Current Liabilities	57,608	93,493
Long-term debt	281,000	135,000
Other long-term liabilities and deferred credits	6,933	4,572
Total Long-term Liabilities	287,933	139,572
Commitments and Contingencies (Note 13)	'	'
Equity:	'	'
Predecessor Equity	0	88,251
General partner (834,391 and 826,531 units issued and outstanding at June 30, 2014 and December 31, 2013)	-30,352	14,078
Total Partnersb Equity	720,429	832,192
Noncontrolling interests	1,345	0
Total Equity	721,774	832,192
Total Liabilities and Equity	1,067,315	1,065,257
Common unitholders [Member]	'	'
Equity:	'	'
Unitholders	475,227	455,197
Subordinated unitholder [Member]	'	'
Equity:	'	'
Unitholders	$275,554	$274,666

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical)	Jun. 30, 2014	Dec. 31, 2013
General partner units issued (in shares)	834,391	826,531
General partner units outstanding (in shares)	834,391	826,531
Common unitholders [Member]	'	'
Unitholders units issued (in shares)	24,685,140	24,300,000
Unitholders units outstanding (in shares)	24,685,140	24,300,000
Subordinated unitholder [Member]	'	'
Unitholders units issued (in shares)	16,200,000	16,200,000
Unitholders units outstanding (in shares)	16,200,000	16,200,000

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Natural gas liquids sales	$36,329	$31,690	$85,236	$65,091
Natural gas sales	2,713	4,248	7,521	4,698
Transportation services	30,569	30,909	64,673	60,527
Processing and other revenues	7,709	2,500	14,669	4,719
Total Revenues	77,320	69,347	172,099	135,035
Operating Costs and Expenses:	'	'	'	'
Cost of sales and transportation services	41,172	35,257	93,240	66,443
Operations and maintenance	10,055	9,229	18,068	16,592
Depreciation and amortization	8,768	9,332	16,320	18,722
General and administrative	7,124	6,517	13,773	12,544
Taxes, other than income taxes	1,639	1,663	3,595	3,709
Total Operating Costs and Expenses	68,758	61,998	144,996	118,010
Operating Income	8,562	7,349	27,103	17,025
Other (Expense) Income:	'	'	'	'
Interest (expense) income, net	-2,140	-3,495	-3,433	-9,059
Gain on remeasurement of unconsolidated investment	9,388	0	9,388	0
Loss on extinguishment of debt	0	-17,526	0	-17,526
Equity in earnings of unconsolidated investment	273	0	717	0
Other income, net	729	445	1,669	801
Total Other Expense	8,250	-20,576	8,341	-25,784
Net Income (Loss)	16,812	-13,227	35,444	-8,759
Net loss attributable to noncontrolling interests	55	0	55	0
Net Income (loss) attributable to partners	16,867	-13,227	35,499	-8,759
Total comprehensive income attributable to partners	16,867	-13,227	35,499	-8,759
Allocation of income (loss) to the limited partners:	'	'	'	'
Net Income (loss) attributable to partners	16,867	-13,227	35,499	-8,759
Predecessor operations interest in net loss (income)	0	1,500	-5,732	2,103
Net income (loss) attributable to partners excluding predecessor operations interest in net loss (income)	16,867	-11,727	29,767	-6,656
General partner interest in net (income) loss subsequent to May 17, 2013	-1,096	-1,638	-1,477	-6,709
Common and subordinated unitholders' interest in net income (loss) subsequent to May 17, 2013	15,771	-13,365	28,290	-13,365
Basic net income (loss) per common and subordinated unit (usd per share)	$0.39	($0.33)	$0.70	($0.33)
Diluted net income (loss) per common and subordinated unit (usd per share)	$0.38	($0.33)	$0.68	($0.33)
Basic average number of common and subordinated units outstanding (in shares)	40,885	40,246	40,694	40,246
Diluted average number of common and subordinated units outstanding (in shares)	41,905	40,246	41,624	40,246
Prior to May 17, 2013	'	'	'	'
Allocation of income (loss) to the limited partners:	'	'	'	'
Net income (loss) attributable to partners excluding predecessor operations interest in net loss (income)	0	-1,911	0	-6,982
Subsequent to May 17, 2013	'	'	'	'
Allocation of income (loss) to the limited partners:	'	'	'	'
Net income (loss) attributable to partners excluding predecessor operations interest in net loss (income)	16,867	-13,638	29,767	-13,638
General partner interest in net (income) loss subsequent to May 17, 2013	-1,096	273	-1,477	273
Common and subordinated unitholders' interest in net income (loss) subsequent to May 17, 2013	$15,771	($13,365)	$28,290	($13,365)

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash Flows from Operating Activities:	'	'
Net Income (Loss)	$35,444	($8,759)
Adjustments to reconcile net income (loss) to net cash flows from operating activities:	'	'
Depreciation and amortization	16,956	19,940
Gain on remeasurement of unconsolidated investment	-9,388	0
Loss on extinguishment of debt	0	17,526
Noncash compensation expense	2,249	85
Changes in components of working capital:	'	'
Accounts receivable and other	4,144	18,683
Gas imbalances	831	2,517
Inventories	-867	-2,592
Accounts payable and accrued liabilities	-17,249	-9,484
Other operating, net	2,833	-5,233
Net Cash Provided by Operating Activities	-34,953	-32,683
Cash Flows from Investing Activities:	'	'
Acquisition of Trailblazer	-150,000	0
Capital expenditures	-19,851	-20,724
Acquisition of additional equity interests in Water Solutions	-7,600	0
Unconsolidated investment	-1,999	0
Other investing, net	358	-341
Net Cash Used in Investing Activities	-179,092	-21,065
Cash Flows from Financing Activities:	'	'
Borrowings under revolving credit facility	146,000	224,000
Contribution from TD	27,488	0
Distributions to unitholders	-26,770	0
Reimbursement of stock compensation expense from TD	2,392	0
Distributions to Predecessor Member, net	-2,893	-1,215
Payments for deferred financing costs	-2,325	-4,988
Repayment of debt assumed from TD	0	-400,000
Proceeds from initial public offering, net of offering costs	0	290,706
Distributions to Member, net	0	-118,538
Other financing, net	263	-308
Net Cash Provided by (Used in) Financing Activities	144,155	-10,343
Net Change in Cash and Cash Equivalents	16	1,275
Cash and Cash Equivalents, beginning of period	0	0
Cash and Cash Equivalents, end of period	16	1,275
Supplemental Disclosures:	'	'
Cash payments for interest	2,239	561
Schedule of Noncash Investing and Financing Activities:	'	'
Increase in accrual for payment of property, plant and equipment	0	484
Receivable for unreimbursed stock compensation from TD	413	0
Fair value of TIGT and TMID assets contributed by TD	0	1,027,127
Fair value of TIGT and TMID liabilities contributed by TD	$0	($566,849)

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL (UNAUDITED) (USD $)

Total

Partner Capital Components [Domain]

Noncontrolling Interest [Member]

Total Partner Equity Including Portion Attributable to Noncontrolling Interest [Member]

Predecessor [Member]

Limited Partners [Member]

Limited Partners [Member]

General Partner [Member]

Trailblazer [Member]

Trailblazer [Member]

Trailblazer [Member]

Trailblazer [Member]

BNN Water Solutions [Member]

BNN Water Solutions [Member]

In Thousands, unless otherwise specified

Common unitholders [Member]

Subordinated unitholder [Member]

Partner Capital Components [Domain]

Total Partner Equity Including Portion Attributable to Noncontrolling Interest [Member]

Predecessor [Member]

Limited Partners [Member]

Noncontrolling Interest [Member]

Total Partner Equity Including Portion Attributable to Noncontrolling Interest [Member]

Common unitholders [Member]

Beginning Balance at Dec. 31, 2013

$832,192

$832,192

$0

$832,192

$88,251

$455,197

$274,666

$14,078

'

'

'

'

'

'

Increase (Decrease) in Partners' Capital [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income

35,499

35,499

-55

35,444

5,732

17,034

11,256

1,477

'

'

'

'

'

'

Distributions to Predecessor Member, net

'

-2,893

'

-2,893

-2,893

'

'

'

'

'

'

'

'

'

Acquisitions

'

'

'

'

'

'

'

'

-77,067

-77,067

-91,090

14,023

1,400

1,400

Excess purchase price over carrying value of acquired interests in Trailblazer

'

-72,933

'

-72,933

'

'

'

-72,933

'

'

'

'

'

'

Contributions

'

27,488

'

27,488

'

'

'

27,488

'

'

'

'

'

'

Issuance of general partner units

'

263

'

263

'

'

'

263

'

'

'

'

'

'

Distributions to unitholders

'

-26,770

'

-26,770

'

-15,677

-10,368

-725

'

'

'

'

'

'

Noncash compensation expense

'

4,650

'

4,650

'

4,650

'

'

'

'

'

'

'

'

Ending Balance at Jun. 30, 2014

720,429

720,429

1,345

721,774

0

475,227

275,554

-30,352

'

'

'

'

'

'

Beginning Balance at Mar. 31, 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Partners' Capital [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income

16,867

'

'

'

'

'

'

'

'

'

'

'

'

'

Excess purchase price over carrying value of acquired interests in Trailblazer

'

'

'

'

'

'

'

-72,900

'

'

'

'

'

'

Ending Balance at Jun. 30, 2014

$720,429

'

'

'

'

'

'

($30,352)

'

'

'

'

'

'

Description_of_Business

Description of Business	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Description of Business	'
	Description of Business
	Tallgrass Energy Partners, LP (“TEP” or the “Partnership”) is a Delaware limited partnership formed in February 2013.
	On May 17, 2013, TEP closed its initial public offering (“IPO”). The 14,600,000 common units held by the public constitute approximately 36% of TEP’s aggregate outstanding common and subordinated units and approximately 35% of TEP’s aggregate outstanding common, subordinated and general partner units at June 30, 2014. Tallgrass Development, LP (“TD”) held 10,085,140 common units and 16,200,000 subordinated units at June 30, 2014, which comprised approximately 64% of TEP’s aggregate outstanding common and subordinated units and approximately 63% of TEP’s aggregate outstanding common, subordinated and general partner units. In addition, 834,391 general partner units, representing a 2% general partner interest in TEP at June 30, 2014, and all of the incentive distribution rights (“IDRs”) are held by Tallgrass MLP GP, LLC (the “general partner”). In connection with the IPO, TEP entered into a revised partnership agreement on May 17, 2013. The amended and restated partnership agreement requires TEP to distribute its available cash on a quarterly basis, subject to certain terms and conditions, beginning with the quarter ending June 30, 2013. For additional information, see Note 9 – Partnership Equity and Distributions. As discussed in Note 15 – Subsequent Events, TEP closed on a public offering of an additional 8,050,000 common units on July 25, 2014.
	The term “TEP Predecessor” refers to Tallgrass Energy Partners Predecessor, which is comprised of the businesses described below that were owned by TD, from November 13, 2012 through the completion of the IPO on May 17, 2013.
	The businesses included in the TEP Predecessor consist of:
	•	Tallgrass Interstate Gas Transmission, LLC (“TIGT”), which owns an interstate gas pipeline and storage system (the “TIGT System”) that is regulated by the FERC. TIGT currently has approximately 4,645 miles of varying diameter natural gas transmission lines in Colorado, Kansas, Missouri, Nebraska and Wyoming.
	•	Tallgrass Midstream, LLC (“TMID”), which owns and operates one treating and two processing plants in Wyoming.
	The term "Predecessor Entity" refers to Trailblazer Pipeline Company LLC ("Trailblazer"), which TEP acquired on April 1, 2014, as further discussed in Note 2 – Summary of Significant Accounting Policies. Financial results for all prior periods have been recast to reflect the operations of the Predecessor Entity.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	These unaudited condensed consolidated financial statements and related notes for the three and six months ended June 30, 2014 and 2013 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of generally accepted accounting principles 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 disclosures required by GAAP for annual periods. The unaudited condensed consolidated financial statements for the three and six months ended June 30, 2014 and 2013 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair presentation 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. Certain prior period amounts have been reclassified to conform to the current presentation.
	TEP’s financial results for the three and six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014. These unaudited condensed consolidated financial statements should be read in conjunction with TEP’s audited consolidated financial statements and notes thereto included in its Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”) filed with the United States Securities and Exchange Commission (the “SEC”) on March 11, 2014.
	The accompanying consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to TEP by TD in connection with the IPO, for the periods prior to May 17, 2013, the closing date of TEP’s IPO, as well as Trailblazer for the periods prior to April 1, 2014, the date TEP acquired Trailblazer from TD, and include charges from TD for direct costs and allocations of indirect corporate overhead. Management believes that the allocation methods are reasonable, and that the allocations are representative of costs that would have been incurred on a stand-alone basis. Both TEP and TEP Predecessor are considered “entities under common control” as defined under GAAP and, as such, the transfers between the entities of the assets and liabilities has been recorded by TEP at historical cost. TEP, or the Partnership, as used herein refers to the consolidated financial results and operations for TEP Predecessor from its inception through its contribution to TEP and thereafter.
	As further discussed in Note 3 – Business Combinations, TEP closed the acquisition of Trailblazer on April 1, 2014. As the acquisition of Trailblazer is considered a transaction between entities under common control, and a change in reporting entity, the financial information presented for prior periods has been recast to include Trailblazer for all periods presented.
	The condensed consolidated financial statements include the accounts of TEP and its subsidiaries. Significant intra-entity items have been eliminated in the presentation. Net equity distributions of the TEP Predecessor and the Predecessor Entity included in the Consolidated Statements of Cash Flows represent transfers of cash as a result of TD’s centralized cash management systems prior to May 17, 2013, and prior to April 1, 2014 for Trailblazer, under which cash balances were swept daily and recorded as loans from the subsidiaries to TD. These loans were then periodically recorded as equity distributions.
	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 TEP’s 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.
	Accounting Pronouncements Issued But Not Yet Effective
	Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers (Topic 606)”
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 provides a comprehensive and converged set of principles-based revenue recognition guidelines which supersede the existing industry and transaction-specific standards. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve this core principle, entities must apply a five step process to (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 also mandates disclosure of sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The disclosure requirements include qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract.
	The amendments in ASU 2014-09 are effective for public entities for annual reporting periods beginning after December 15, 2016, and for interim periods within that reporting period. Early application is not permitted. The adoption of ASU 2014-09 is not expected to have a material impact on TEP's financial position and results of operations.
	ASU No. 2014-12, "Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period"
	In June 2014, The FASB issued ASU No. 2014-12, Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 provides explicit guidance on accounting for share-based payments requiring a specific performance target to be achieved in order for employees to become eligible to vest in the awards when that performance target may be achieved after the requisite service period for the award. The ASU requires that such performance targets be treated as a performance condition, and should not be reflected in the estimate of the grant-date fair value of the award. Instead, compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved. ASU 2014-12 is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The adoption of ASU 2014-12 is not expected to have a material impact on TEP's financial position and results of operations.

Business_Combinations

Business Combinations	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Business Combinations	'
	Business Combinations
	On April 1, 2014, TEP closed the acquisition of Trailblazer from a wholly owned subsidiary of TD for total consideration valued at approximately $164 million, consisting of $150 million in cash and the issuance of 385,140 common units (valued at approximately $14 million based on the March 31, 2014 closing price of TEP’s common units). On that same date, the general partner contributed additional capital in the amount of approximately $263,000 in exchange for the issuance of 7,860 general partner units in order to maintain its 2% general partner interest. The acquisition of Trailblazer represents a change in reporting entity and a transaction between entities under common control. The excess purchase price over the net book value of Trailblazer's assets and liabilities was accounted for as a deemed distribution as discussed further in Note 9 – Partnership Equity and Distributions.
	Historical Financial Information
	The results of our acquisition of Trailblazer are included in the consolidated balance sheets as of June 30, 2014 and December 31, 2013. The following table presents the previously reported December 31, 2013 consolidated balance sheet, adjusted for the acquisition of Trailblazer from TD:
			As of December 31, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
	ASSETS
	Current Assets:
	Accounts receivable, net		$	27,615			$	2,418			$	30,033
	Gas imbalances		2,598				530				3,128
	Inventories		5,148				401				5,549
	Prepayments and other current assets		16,986				—				16,986
	Total Current Assets		52,347				3,349				55,696
	Property, plant and equipment, net		594,911				62,869				657,780
	Goodwill		304,474				30,241				334,715
	Unconsolidated investment		1,255				—				1,255
	Deferred financing costs		4,512				—				4,512
	Deferred charges and other assets		10,299				1,000				11,299
	Total Assets		$	967,798			$	97,459			$	1,065,257
	LIABILITIES AND PARTNERS’ EQUITY
	Current Liabilities:
	Accounts payable		$	54,621			$	5,619			$	60,240
	Accounts payable to related parties		7,134				3				7,137
	Gas imbalances		3,142				522				3,664
	Derivative liabilities at fair value		184				—				184
	Accrued taxes		4,427				1,093				5,520
	Accrued other current liabilities		14,777				1,971				16,748
	Total Current Liabilities		84,285				9,208				93,493
	Long-term debt		135,000				—				135,000
	Other long-term liabilities and deferred credits		4,572				—				4,572
	Total Long-term Liabilities		139,572				—				139,572
	Partners’ Equity:
	Net Equity		743,941				88,251				832,192
	Total Partners’ Equity		743,941				88,251				832,192
	Total Liabilities and Partners’ Equity		$	967,798			$	97,459			$	1,065,257
	The results of our acquisition of Trailblazer are included in the condensed consolidated statements of income for the three and six months ended June 30, 2014 and 2013. The following tables present the previously reported condensed consolidated statements of income for the three and six months ended June 30, 2013, adjusted for the acquisition of Trailblazer from TD:
			Three Months Ended June 30, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
	Revenues:
	Natural gas liquids sales		$	31,690			$	—			$	31,690
	Natural gas sales		3,888				360				4,248
	Transportation services		25,324				5,585				30,909
	Processing and other revenues		2,500				—				2,500
	Total Revenues		63,402				5,945				69,347
	Operating Costs and Expenses:
	Cost of sales and transportation services		32,358				2,899				35,257
	Operations and maintenance		8,305				924				9,229
	Depreciation and amortization		7,436				1,896				9,332
	General and administrative		5,039				1,478				6,517
	Taxes, other than income taxes		1,394				269				1,663
	Total Operating Costs and Expenses		54,532				7,466				61,998
	Operating Income (Loss)		8,870				(1,521		)		7,349
	Other (Expense) Income:
	Interest (expense) income, net		(3,500		)		5				(3,495		)
	Loss on extinguishment of debt		(17,526		)		—				(17,526		)
	Other income, net		429				16				445
	Total Other (Expense) Income		(20,597		)		21				(20,576		)
	Net Loss		$	(11,727	)		$	(1,500	)		$	(13,227	)
			Six Months Ended June 30, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
Revenues:
Natural gas liquids sales		$	65,091			$	—			$	65,091
Natural gas sales		4,189				509				4,698
Transportation services		49,661				10,866				60,527
Processing and other revenues		4,719				—				4,719
Total Revenues		123,660				11,375				135,035
Operating Costs and Expenses:
Cost of sales and transportation services		61,828				4,615				66,443
Operations and maintenance		14,840				1,752				16,592
Depreciation and amortization		14,982				3,740				18,722
General and administrative		9,673				2,871				12,544
Taxes, other than income taxes		3,171				538				3,709
Total Operating Costs and Expenses		104,494				13,516				118,010
Operating Income (Loss)		19,166				(2,141		)		17,025
Other (Expense) Income:
Interest (expense) income, net		(9,064		)		5				(9,059		)
Loss on extinguishment of debt		(17,526		)		—				(17,526		)
Other income, net		768				33				801
Total Other (Expense) Income		(25,822		)		38				(25,784		)
Net Loss		$	(6,656	)		$	(2,103	)		$	(8,759	)
Formation of BNN Water Solutions, LLC
On November 26, 2013, TEP, through its wholly-owned subsidiary Tallgrass Energy Investments, LLC (“TEI”), entered into a joint venture agreement with BNN Energy LLC (“BNN”) to form Grasslands Water Services I, LLC (“GWSI”). GWSI subsequently built and began operating an intrastate water pipeline in Colorado. TEP accounted for its 50% equity interest in GWSI as an equity method investment. On May 13, 2014, TEI entered into a contribution agreement with BNN and several other parties to form a new entity known as BNN Water Solutions, LLC (“Water Solutions”). Under the terms of the contribution agreement, TEI agreed to contribute its existing 50% interest in GWSI, along with $7.6 million cash, in exchange for an 80% equity interest in Water Solutions. As part of the transaction, GWSI was renamed BNN Redtail, LLC (“Redtail”), became a subsidiary of Water Solutions, and issued preferred equity interests to TEI. Among the assets contributed by BNN and the other parties to the transaction were the other 50% interest in GWSI and a 100% equity interest in Alpha Reclaim Technology, LLC (“Alpha”), a company which sources treated wastewater from municipalities. Alpha is wholly-owned by Redtail.
Upon closing of the transaction, TEP obtained a controlling financial interest in Water Solutions and accordingly has accounted for the transaction as a step acquisition under ASC 805. On the acquisition date, TEP remeasured its previously held 50% equity interest in GWSI to its fair value of $11.9 million, recognized a gain of $9.4 million, and consolidated Water Solutions. The 20% equity interest in Water Solutions held by noncontrolling interests was recorded at its acquisition date fair value of $1.4 million. The fair values of the previously held equity interest and the noncontrolling interest were determined using a discounted cash flow based on forecasted cash flows for the business. These fair value measurements are based on significant inputs 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 following represents the fair value of assets acquired and liabilities assumed at May 13, 2014:
Accounts receivable	$	790
Property, plant and equipment	4,100
Intangible assets	8,200			(1)
Accounts payable and accrued liabilities	(134		)
Distribution payable	(634		)
Net identifiable assets acquired	12,322
Goodwill	8,573
Net assets acquired	$	20,895
(1)	The $8.2 million intangible asset acquired represents a major customer contract and is subject to amortization over the remaining contract term (approximately 1.6 years). Amortization of $0.7 million was recorded during the period from May 13, 2014 to June 30, 2014.
At June 30, 2014, the assets acquired and liabilities assumed in the acquisition were recorded at provisional amounts based on the preliminary purchase price allocation. TEP is in the process of obtaining additional information to identify and measure 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.
Actual revenue and net loss attributable to TEP from Water Solutions of $0.9 million and $0.2 million, respectively, was recognized in the accompanying Condensed Consolidated Statements of Income for the period from May 13, 2014 to June 30, 2014.
Pro Forma revenue and net income attributable to TEP for the three and six months ended June 30, 2014 is presented in the following table. No pro forma information is presented for the three and six months ended June 30, 2013 as Water Solutions did not begin commercial operations until the first quarter of 2014.
	Three Months Ended June 30, 2014				Six Months Ended June 30, 2014
	(in thousands)
Revenue	$	78,084			$	174,540
Net income attributable to TEP	$	7,642			$	26,541
This unaudited pro forma financial information for TEP is presented as if the acquisition of Water Solutions had been completed on January 1, 2013. The pro forma financial information is not necessarily indicative of what the actual results of operations or financial position of TEP would have been if the transactions had in fact occurred on the date or for the period indicated, nor do they purport to project the results of operations or financial position of TEP Predecessor 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 transactions or the costs to achieve these cost savings, operating synergies, and revenue enhancements. The pro forma revenue and net income includes adjustments for the three and six months ended June 30, 2014 to give effect to the following:
(a)	Reduction in net income attributable to TEP to remove equity in earnings of GWSI recorded for the period from January 1, 2014 to May 13, 2014.
(b)	Increase in revenue and net income attributable to TEP to reflect TEP's consolidated 80% equity interest in the operations of GWSI for the period from January 1, 2014 to May 13, 2014.
(c)	Reduction in net income attributable to TEP to remove gain on remeasurement of previously held equity interest in GWSI.
Reconciliation of Goodwill
The following table presents a reconciliation of the carrying amount of goodwill by reportable segment for the reporting period:
	Three Months Ended June 30, 2014												Three Months Ended June 30, 2013
	Gas Transportation and storage				Processing				Total				Gas Transportation and storage		Processing		Total
					(in thousands)										(in thousands)
Balance at beginning of period	$	255,558			$	79,157			$	334,715			$	255,100	$	78,057	$	333,157
Goodwill acquired	—				8,573			(1)	8,573				—		—		—
Balance at end of period	$	255,558			$	87,730			$	343,288			$	255,100	$	78,057	$	333,157
	Six Months Ended June 30, 2014												Six Months Ended June 30, 2013
	Gas Transportation and storage				Processing				Total				Gas Transportation and storage		Processing		Total
					(in thousands)										(in thousands)
Balance at beginning of period	$	255,558			$	79,157			$	334,715			$	255,100	$	78,057	$	333,157
Goodwill acquired	—				8,573			(1)	8,573				—		—		—
Balance at end of period	$	255,558			$	87,730			$	343,288			$	255,100	$	78,057	$	333,157
(1)    The $8.6 million of goodwill was recorded in connection with the acquisition of a controlling interest in Water Solutions on May 13, 2014.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	TEP has no employees. Beginning November 13, 2012, TD, through its wholly-owned subsidiary Tallgrass Operations, LLC ("Tallgrass Operations"), provided and charged TEP for all direct and indirect costs of services provided to us or incurred on our behalf including employee labor costs, information technology services, employee health and life benefits, and all other expenses necessary or appropriate to the conduct of our business. TEP recorded these costs on the accrual basis in the period in which TD incurred them. Each of the wholly-owned companies comprising TEP had an agency arrangement with TD under which TD paid costs and expenses incurred by TEP, acted as an agent for TEP, and was reimbursed by TEP for such payments.
	On May 17, 2013, in connection with the closing of TEP’s IPO, TEP and its general partner entered into an Omnibus Agreement with TD and certain of its affiliates, including Tallgrass Operations (the “Omnibus Agreement”). The Omnibus Agreement provides that, among other things, TEP will reimburse TD and its affiliates for all expenses they incur and payments they make on TEP’s behalf, including the costs of employee and director compensation and benefits as well as the cost of the provision of certain centralized corporate functions performed by TD, including legal, accounting, cash management, insurance administration and claims processing, risk management, health, safety and environmental, information technology and human resources in each case to the extent reasonably allocable to TEP.
	For the calendar year 2014, TEP’s annual cost reimbursements to TD for costs discussed above, are expected to be $20.4 million, inclusive of costs associated with our acquisition of Trailblazer in April 2014 and our consolidation of Water Solutions in May 2014. TEP also pays a quarterly reimbursement to TD for costs associated with being a public company. The quarterly public company reimbursement was $625,000 for the second quarter of 2014 and TEP currently expects it to remain the same for each subsequent quarter in 2014. However, these reimbursement amounts will be periodically reviewed and adjusted as necessary to continue to reflect reasonable allocation of costs to TEP.
	Due to the cash management agreement discussed in Note 2 – Summary of Significant Accounting Policies, intercompany balances at the Predecessor Entity were periodically settled and treated as equity distributions prior to the completion of the IPO on May 17, 2013 and prior to April 1, 2014 for Trailblazer.
	Totals of transactions with affiliated companies are as follows:
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
		(in thousands)
	Charges to TEP: (1)
	Operation and maintenance	$	4,608	$	4,597	$	8,956	$	8,716
	General and administrative (2)	$	4,305	$	6,247	$	8,887	$	12,200
	(1)	Charges to TEP include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three and six months ended June 30, 2014 and 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in allocated amounts for general and administrative costs.
	There were no balances with affiliates included in "Accounts receivable" in the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013. Details of balances with affiliates included in “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
		30-Jun-14		31-Dec-13
		(in thousands)
	Payables to affiliated companies:
	Accounts payable to Tallgrass Operations, LLC	$	3,921	$	7,106
	Accounts payable to Rockies Express Pipeline LLC	42		31
	Total payables to affiliated companies	$	3,963	$	7,137
	Balances of gas imbalances with affiliated shippers are as follows:
		30-Jun-14		31-Dec-13
		(in thousands)
	Affiliate gas balance receivables	$	—	$	137
	Affiliate gas balance payables	$	803	$	122
	Pursuant to the terms of a Purchase and Sale Agreement dated August 1, 2012, TD, on behalf of its wholly-owned subsidiary, Tallgrass Pony Express Pipeline, LLC (“Pony Express”), is reimbursing TIGT for all costs TIGT incurs with respect to the Pony Express Abandonment, as defined in Note 12 – Regulatory Matters, including, but not limited to, development costs, capital costs and related interest costs associated with the construction of certain gas facilities necessary to maintain existing natural gas service on the TIGT System (the “Replacement Gas Facilities”). The Replacement Gas Facilities are required as part of the Pony Express Abandonment in order for TIGT to continue service to existing customers after having sold approximately 430 miles of natural gas pipeline, and associated rights of way and certain other equipment, to Pony Express in 2013. For more information, see Note 12 – Regulatory Matters.
	TIGT’s expenditures for the Replacement Gas Facilities are captured in “Prepayments and other current assets” in the Condensed Consolidated Balance Sheets as they are incurred and interest is accrued until reimbursement takes place (which is typically monthly). During the six months ended June 30, 2014 we received proceeds from TD of $67.1 million and incurred expenditures of $39.2 million. We recognized a contribution of $27.5 million from TD in our Condensed Consolidated Statement of Partners' Capital which represents the difference between the carrying amount of the Replacement Gas Facilities and the proceeds received from TD, and $0.4 million in "Accrued and other current liabilities" related to the timing of cash expenditures and reimbursement from TD. At December 31, 2013, TEP had $17.0 million in “Prepayments and other current assets” related to this project that were cash settled by TD in the first quarter of 2014.

Inventory

Inventory	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Inventory	'
	Inventory
	The components of inventory at June 30, 2014 and December 31, 2013 consisted of the following:
		30-Jun-14		31-Dec-13
		(in thousands)
	Materials and supplies	$	2,187	$	2,137
	Natural gas liquids	1,210		1,009
	Gas in underground storage	4,725		2,403
	Total inventory	$	8,122	$	5,549

Property_Plant_and_Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	Property, Plant and Equipment
	A summary of net property, plant and equipment by classification is as follows:
		30-Jun-14			31-Dec-13
		(in thousands)
	Natural gas pipelines	$	419,409		$	397,287
	Processing and treating assets	237,964			209,329
	General and other	30,606			26,076
	Construction work in progress	7,843			47,352
	Accumulated depreciation and amortization	(35,571		)	(22,264		)
	Total property, plant and equipment, net	$	660,251		$	657,780

Risk_Management

Risk Management

6 Months Ended

Jun. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

'

Risk Management

'

Risk Management

TEP occasionally enters into derivative contracts with third parties for the purpose of hedging exposures that accompany its normal business activities. TEP’s normal business activities expose it to risks associated with changes in the market price of commodities, including, among others, natural gas. Specifically, the risks associated with changes in the market price of natural gas, include, among others (i) pre-existing or anticipated physical natural gas sales, (ii) natural gas purchases and (iii) natural gas system use and storage. TEP has 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 TEP’s derivative contracts included in the accompanying Condensed Consolidated Balance Sheets:

Balance Sheet

30-Jun-14

31-Dec-13

Location

(in thousands)

Energy commodity derivative contracts

Current liabilities

$

439

$

184

TEP had no derivative contracts in asset positions as of June 30, 2014 or December 31, 2013. As of June 30, 2014, the fair value shown for commodity contracts was comprised of derivative volumes for short and long fixed-price swaps totaling 0.6 Bcf and 0.6 Bcf, respectively.

Effect of Derivative Contracts on the Income Statement

The following table summarizes the impact of derivative contracts included in the accompanying Condensed Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2014 and 2013:

Location of

Amount of gain (loss) recognized in income on derivatives

gain (loss) recognized

in income on

Three Months Ended June 30,

Six Months Ended June 30,

derivatives

2014

2013

2014

2013

(in thousands)

Derivatives not designated as hedging contracts:

Energy commodity derivative contracts

Natural gas sales

$

(106

)

$

635

$

(458

)

$

(284

)

Credit Risk

TEP has counterparty credit risk as a result of its use of derivative contracts. TEP’s counterparties consist of major financial institutions. This concentration of counterparties may impact TEP’s 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.

TEP maintains credit policies that it believes minimize its overall credit risk. These policies include (i) an evaluation of potential counterparties’ financial condition (including credit ratings), (ii) collateral requirements under certain circumstances and (iii) the use of standardized agreements which allow for netting of positive and negative exposure associated with a single counterparty. Based on its policies and exposure, TEP’s management does not currently anticipate a material adverse effect on TEP’s financial position, results of operations, or cash flows as a result of counterparty performance.

TEP’s over-the-counter swaps are entered into with counterparties outside central trading organizations such as a futures, options or stock exchange. These contracts are with financial institutions with investment grade credit ratings. While TEP enters into derivative transactions principally with investment grade counterparties and actively monitors their ratings, it is nevertheless possible that from time to time losses will result from counterparty credit risk in the future. As of June 30, 2014, the fair value of TEP’s derivative contracts was a liability, resulting in no credit exposure from TEP’s counterparties as of that date.

In addition, when the market value of TEP’s derivative contracts with specific counterparties exceeds established limits, TEP is required to provide collateral to its counterparties, which may include posting letters of credit or placing cash in margin accounts. Accordingly, entity valuation adjustments are necessary to reflect the effect of TEP’s own credit quality on the fair value of TEP’s net liability position with each counterparty. The methodology to determine this adjustment is consistent with how TEP evaluates counterparty credit risk, taking into account current credit spreads for its comparative industry sector, as well as any change in such spreads since the last measurement date. As of June 30, 2014 and December 31, 2013, TEP did not have any outstanding letters of credit or cash in margin accounts in support of its hedging of commodity price risks associated with the sale of natural gas nor did TEP have margin deposits with counterparties associated with energy commodity contract positions.

Fair Value

Derivative assets and liabilities are measured and reported at fair value. Derivative contracts can be exchange-traded or over-the-counter (“OTC”). Exchange-traded derivative contracts typically fall within Level 1 of the fair value hierarchy if they are traded in an active market. TEP values exchange-traded derivative contracts using quoted market prices for identical securities.

OTC 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. TEP uses 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.

Certain OTC derivative contracts trade in less liquid markets with limited pricing information; as such, the determination of fair value for these derivative contracts is inherently more difficult. Such contracts are classified within Level 3 of the fair value hierarchy. The valuations of these less liquid OTC derivatives are typically impacted by Level 1 and/or Level 2 inputs that can be observed in the market, as well as unobservable Level 3 inputs. Use of a different valuation model or different valuation input values could produce a significantly different estimate of fair value. However, derivative contracts valued using inputs unobservable in active markets are generally not material to TEP’s financial statements.

When appropriate, valuations are adjusted for various factors including credit considerations. Such adjustments are generally based on available market evidence. In the absence of such evidence, management’s best estimate is used.

The following tables summarize the fair value measurements of TEP’s energy commodity derivative contracts in a liability position as of June 30, 2014 and December 31, 2013 based on the fair value hierarchy established by the Codification:

Liability fair value measurements using

Total

Quoted prices in

Significant

Significant

active markets

other observable

unobservable

for identical

inputs

inputs

assets

(Level 2)

(Level 3)

(Level 1)

(in thousands)

TEP as of June 30, 2014

Energy commodity derivative contracts

$

439

$

—

$

439

$

—

TEP as of December 31, 2013

Energy commodity derivative contracts

$

184

$

—

$

184

$

—

Longterm_Debt

Long-term Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Long-term Debt	'
	Long-term Debt
	Revolving Credit Facility
	TEP has a senior secured revolving credit facility with Barclays Bank PLC, as administrative agent, and a syndicate of lenders (the "Credit Agreement") which will mature on May 17, 2018. On June 25, 2014, TEP and certain of its subsidiaries entered into Amendment No. 1 (the "Amendment") to the Credit Agreement dated as of May 17, 2013. The Amendment modifies certain provisions of the Credit Agreement to, among other things, (i) increase the amount of the revolving facility from $500 million to $850 million, (ii) increase the sublimit for swing line loans to $60 million, (iii) increase the sublimit for letters of credit to $75 million, (iv) increase the accordion feature to allow the Partnership to borrow up to an additional $250 million, subject to the Partnership's receipt of increased or new commitments from lenders and satisfaction of certain other conditions, and (v) reduce the applicable margin for loans by 0.25%.
	The following table sets forth the outstanding borrowings, letters of credit issued, and available borrowing capacity under the revolving credit facility as of June 30, 2014 and December 31, 2013:
		30-Jun-14			31-Dec-13
		(in thousands)
	Total capacity under the revolving credit facility	$	850,000		$	500,000
	Less: Outstanding borrowings under the revolving credit facility	(281,000		)	(135,000		)
	Less: Letters of credit issued under the revolving credit facility	—			(654		)
	Available capacity under the revolving credit facility	$	569,000		$	364,346
	The credit facility contains various covenants and restrictive provisions that, among other things, limit or restrict TEP’s ability (as well as the ability of TEP’s restricted subsidiaries) to incur or guarantee additional debt, incur certain liens on assets, dispose of assets, make certain distributions (including distributions from available cash, if a default or event of default under the credit agreement then exists or would result from making such a distribution), change the nature of TEP’s business, engage in certain mergers or make certain investments and acquisitions, enter into non-arms-length transactions with affiliates and designate certain subsidiaries as “Unrestricted Subsidiaries.” Currently, no subsidiaries have been designated as Unrestricted Subsidiaries. In addition, TEP is required to maintain a consolidated leverage ratio of not more than 4.75 to 1.00 (which will be increased to 5.25 to 1.00 for certain measurement periods following the consummation of certain acquisitions) and a consolidated interest coverage ratio of not less than 2.50 to 1.00. As of June 30, 2014, TEP is in compliance with the covenants required under the revolving credit facility.
	The unused portion of the credit facility is subject to a commitment fee, which was initially 0.375%, and after June 25, 2014, ranges from 0.300% to 0.500%, based on TEP’s total leverage ratio. As of June 30, 2014, the weighted average interest rate on outstanding borrowings was 1.95%.
	Long-term Debt Allocated from TD
	On November 13, 2012, TD entered into a credit agreement with a syndicate of lenders which included a term loan, a delayed draw term loan and a revolving credit facility. Prior to May 17, 2013, the long-term debt held by TD was guaranteed by TIGT and TMID, and $400 million of that debt was expected to be assumed by TEP in connection with the IPO. As such, $400 million of the term loan, along with the corresponding discount and deferred financing costs, was allocated to TEP as of November 13, 2012. The term loan is an obligation of TD and prior to May 17, 2013, was guaranteed by TIGT and TMID.
	Upon the closing of the IPO on May 17, 2013, TEP legally assumed the previously allocated $400 million portion of the TD term loan and used a portion of the IPO proceeds, along with borrowings under TEP’s revolving credit agreement, to repay its $400 million portion of the term loan, at which time TIGT and TMID were released as guarantors of the TD debt. TEP recognized a loss on extinguishment of debt of $17.5 million during the year ended December 31, 2013 associated with the portion of deferred financing costs and unamortized discount on the amount of the TD term loan that was allocated to TEP.
	Fair Value
	The following table sets forth the carrying amount and fair value of TEP’s long-term debt, which is not measured at fair value in the Condensed Consolidated Balance Sheets as of June 30, 2014 and December 31, 2013, but for which fair value is disclosed:
		Fair Value
		Quoted prices			Significant			Significant		Total		Carrying
		in active markets			other observable			unobservable				Amount
		for identical assets			inputs			inputs
		(Level 1)			(Level 2)			(Level 3)
		(in thousands)
	June 30, 2014	$	—		$	281,000		$	—	$	281,000	$	281,000
	December 31, 2013	$	—		$	135,000		$	—	$	135,000	$	135,000
	The long-term debt borrowed under the revolving credit facility is carried at amortized cost. As of June 30, 2014 and December 31, 2013, the fair value approximates the carrying amount for the borrowings under the revolving credit facility using a discounted cash flow analysis. TEP is not aware of any factors that would significantly affect the estimated fair value subsequent to June 30, 2014.

Partnership_Equity_and_Distrib

Partnership Equity and Distributions

6 Months Ended

Jun. 30, 2014

Equity [Abstract]

'

Partnership Equity and Distributions

'

Partnership Equity and Distributions

TEP’s partnership agreement requires TEP to distribute its available cash, as defined below, to unitholders of record on the applicable record date within 45 days after the end of each quarter, beginning with the quarter ended June 30, 2013. TEP’s partnership agreement provides that available cash, each quarter, is first distributed to the common unitholders and the general partner on a pro rata basis until each common unitholder has received $0.2875 per unit, which amount is defined in TEP’s partnership agreement as the minimum quarterly distribution (“MQD”). During the subordination period, defined below, holders of the subordinated units are not entitled to receive a distribution of available cash until each holder of common units has received the MQD, and if the MQD is not paid for any quarter, the cumulative amount of any arrearages in the payment of the MQD from prior quarters.

The following table shows the distributions for the year ended 2013 and six months ended June 30, 2014:

Distributions

Limited Partners

General Partner

Distributions

Common and

per Limited

Three Months Ended

Date Paid

Subordinated

Incentive

2%

Total

Partner Unit

(in thousands, except per unit amounts)

30-Jun-14

August 14, 2014 (1)

$

18,596

$

758

$

330

$

19,684

$

0.38

March 31, 2014

May 14, 2014

13,288

126

274

13,688

0.325

December 31, 2013

February 12, 2014

12,757

63

262

13,082

0.315

September 30, 2013

November 13, 2013

12,049

—

245

12,294

0.2975

June 30, 2013

August 13, 2013

5,759

—

118

5,877

0.1422

(2)

(1)

The distribution declared on July 1, 2014 for the second quarter of 2014 is expected to be paid August 14, 2014 subsequent to the date of this Quarterly Report on 48,935,140 common units and subordinated units of record at the close of business on July 30, 2014.

(2)

The distribution declared on July 18, 2013 for the second quarter of 2013 represented a prorated amount of the MQD of $0.2875 per common unit, based upon the number of days between the closing of the IPO on May 17, 2013 to June 30, 2013.

Subordinated Units

All subordinated units are currently held by TD. The principal difference between the common units and subordinated units is that in any quarter during the subordination period, holders of the subordinated units are not entitled to receive a distribution of available cash until the holders of common units have received the MQD (inclusive of any cumulative arrearages of previously unpaid MQD from previous quarters). Furthermore, subordinated unitholders are not entitled to receive arrearages from previous quarterly distributions. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be available cash to be distributed on the common units. The subordination period will end, and the subordinated units will convert to common units, on a one-for-one basis, when certain distribution milestones described in the partnership agreement have been met.

Incentive Distribution Rights

As of June 30, 2014, the general partner owns a 2% general partner interest in TEP, which was represented by 834,391 general partner units. As discussed in Note 3 – Business Combinations, in April 2014, in connection with TEP’s acquisition of Trailblazer, the general partner contributed capital in exchange for the issuance of an additional 7,860 general partner units in order to continue to maintain its 2% general partner interest. The general partner also owns all of the IDRs. IDRs represent the right to receive an increasing percentage (13%, 23% and 48%) of quarterly distributions of available cash from operating surplus after the MQD and the target distribution levels have been achieved. The general partner may transfer these rights separately from its general partner interest, subject to restrictions in TEP’s partnership agreement. Under TEP’s partnership agreement, the general partner may at any time contribute additional capital to TEP in order to maintain its 2% general partner interest.

The following discussion related to incentive distributions assumes that TEP’s general partner maintains its 2.0% general partner interest and continues to own all of the IDRs.

If for any quarter:

•

TEP has distributed available cash from operating surplus to all of the common unitholders (and during the subordination period, to the subordinated unitholders) in an amount equal to the MQD for each outstanding unit for such quarter; and

•

TEP has distributed available cash from operating surplus on outstanding common units in an amount necessary to eliminate any cumulative arrearages in the payment of the MQD to common unitholders;

then, TEP will distribute additional available cash from operating surplus for that quarter among the unitholders and the general partner in the following manner:

•

first, 98% to all unitholders, pro rata, and 2% to TEP’s general partner, until each unitholder receives a total of $0.3048 per unit for that quarter (the “first target distribution”);

•

second, 85% to all unitholders, pro rata, and 15% to TEP’s general partner, until each unitholder receives a total of $0.3536 per unit for that quarter (the “second target distribution”);

•

third, 75% to all unitholders, pro rata, and 25% to TEP’s general partner, until each unitholder receives a total of $0.4313 per unit for that quarter (the “third target distribution”); and

•

thereafter, 50% to all unitholders, pro rata, and 50% to TEP’s general partner.

Definition of Available Cash

Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter:

•

less, the amount of cash reserves established by TEP’s general partner to:

•

provide for the proper conduct of TEP’s business (including reserves for future capital expenditures, for anticipated future credit needs subsequent to that quarter, for legal matters and for refunds of collected rates reasonably likely to be refunded as a result of a settlement or hearing related to FERC rate proceedings);

•

comply with applicable law or regulation, any of TEP’s debt instruments or other agreements; or

•

provide funds for distributions to unitholders and to TEP’s general partner for any one or more of the next four quarters (provided that TEP’s general partner may not establish cash reserves for distributions if the effect of the establishment of such reserves will prevent TEP from distributing the MQD on all common units and any cumulative arrearages on such common units for the current quarter);

•

plus, if TEP’s general partner so determines, all or any portion of the cash on hand on the date of distribution of available cash for the quarter, including cash on hand resulting from working capital borrowings made subsequent to the end of such quarter.

Other Distributions

As discussed in Note 2 – Summary of Significant Accounting Policies, prior to May 17, 2013 for TIGT and TMID and prior to April 1, 2014 for Trailblazer, the net amount of transfers for loans made each day through the centralized cash management system, less reimbursement payments under the agency agreement described in Note 4 – Related Party Transactions, was recognized as equity distributions during that time period. During the three and six months ended June 30, 2014, TEP was deemed to have made a noncash, net capital distribution of $72.9 million to the general partner, which represents the excess purchase price over the carrying value of the Trailblazer net assets acquired on April 1, 2014. See Note 3 – Business Combinations for additional information regarding the Trailblazer acquisition. During the period from January 1, 2014 to March 31, 2014, Trailblazer made net distributions to TD of$2.9 million. There were no equity distributions made to TD subsequent to Trailblazer's acquisition by TEP on April 1, 2014.

Net distributions from TEP to TD for the six months ended June 30, 2013 were approximately $119.8 million, respectively, and included the $85.5 million to TD related to the contribution of TIGT and TMID to TEP, the $31.2 million net proceeds from the exercise of the underwriter’s option to purchase additional common units as part of the Offering, and $1.2 million net distributions from Trailblazer to TD.

Net_Income_per_Limited_Partner

Net Income per Limited Partner Unit	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Net Income per Limited Partner Unit	'
	Net Income per Limited Partner Unit
	The Partnership’s net income is allocated to the general partner and the limited partners, including the holders of the subordinated units, in accordance with their respective ownership percentages, after giving effect to incentive distributions paid to the general partner. Basic and diluted net income per limited partner unit is calculated by dividing limited partners’ interest in net income, less general partner incentive distributions, by the weighted average number of outstanding limited partner units during the period.
	TEP computes earnings per unit using the two-class method for Master Limited Partnerships as prescribed in the FASB guidance. The two-class method requires that securities that meet the definition of a participating security be considered for inclusion in the computation of basic earnings per unit. Under the two-class method, earnings per unit is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.
	TEP calculates net income available to limited partners based on the distributions pertaining to the current period’s net income. After adjusting for the appropriate period’s distributions, the remaining undistributed earnings or excess distributions over earnings, if any, are allocated to the general partner and limited partners in accordance with the contractual terms of the partnership agreement and as further prescribed in the FASB guidance under the two-class method.
	The two-class method does not impact TEP’s overall net income or other financial results; however, in periods in which aggregate net income exceeds its aggregate distributions for such period, it will have the impact of reducing net income per limited partner unit. This result occurs as a larger portion of TEP’s aggregate earnings, as if distributed, is allocated to the incentive distribution rights of the general partner, even though TEP makes distributions on the basis of available cash and not earnings. In periods in which TEP’s aggregate net income does not exceed its aggregate distributions for such period, the two-class method does not have any impact on our calculation of earnings per limited partner unit.
	Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted earnings per unit reflects the potential dilution of common equivalent units that could occur if equity participation units are converted into common units.
	As the IPO was completed on May 17, 2013, no income from the period from January 1, 2013 to May 16, 2013 is allocated to the limited partner units that were issued on May 17, 2013 and all income for such period was allocated to the general partner or predecessor operations. All net income or loss from Trailblazer prior to its acquisition on April 1, 2014 is allocated to predecessor operations in the table below.
	The following table illustrates the Partnership’s calculation of net income per common and subordinated unit for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014			Three Months Ended June 30, 2013			Period from April 1, 2013 to May 16, 2013			Period from May 17, 2013 to June 30, 2013
		(in thousands, except per unit amounts)
	Net income (loss)	$	16,812		$	(13,227	)	$	1,722		$	(14,949	)
	Net loss attributable to noncontrolling interests	55			—			—			—
	Net income (loss) attributable to partners	16,867			(13,227		)	1,722			(14,949		)
	Predecessor operations interest in net loss	—			1,500			189			1,311
	General partner interest in net (income) loss	(1,096		)	(1,638		)	(1,911		)	273
	Net income (loss) available to common and subordinated unitholders	$	15,771		$	(13,365	)	$	—		$	(13,365	)
	Basic net income (loss) per common and subordinated unit	$	0.39		$	(0.33	)				$	(0.33	)
	Diluted net income (loss) per common and subordinated unit	$	0.38		$	(0.33	)				$	(0.33	)
	Basic average number of common and subordinated units outstanding	40,885			40,246						40,246
	Equity Participation Unit equivalent units	1,020			—						—
	Diluted average number of common and subordinated units outstanding	41,905			40,246						40,246
		Six Months Ended June 30, 2014			Six Months Ended June 30, 2013			Period from January 1, 2013 to May 16, 2013			Period from May 17, 2013 to June 30, 2013
		(in thousands, except per unit amounts)
	Net income (loss)	$	35,444		$	(8,759	)	$	6,190		$	(14,949	)
	Net loss attributable to noncontrolling interests	55			—			—			—
	Net income (loss) attributable to partners	35,499			(8,759		)	6,190			(14,949		)
	Predecessor operations interest in net (income) loss	(5,732		)	2,103			792			1,311
	General partner interest in net (income) loss	(1,477		)	(6,709		)	(6,982		)	273
	Net income (loss) available to common and subordinated unitholders	$	28,290		$	(13,365	)	$	—		$	(13,365	)
	Basic net income (loss) per common and subordinated unit	$	0.7		$	(0.33	)				$	(0.33	)
	Diluted net income (loss) per common and subordinated unit	$	0.68		$	(0.33	)				$	(0.33	)
	Basic average number of common and subordinated units outstanding	40,694			40,246						40,246
	Equity Participation Unit equivalent units	930			—						—
	Diluted average number of common and subordinated units outstanding	41,624			40,246						40,246

EquityBased_Compensation

Equity-Based Compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	Long-term Incentive Plan
	Effective May 13, 2013, the general partner adopted a Long-term Incentive Plan (“LTIP”) pursuant to which awards in the form of unrestricted units, restricted units, equity participation units, options, unit appreciation rights or distribution equivalent rights may be granted to employees, consultants, and directors of the general partner and its affiliates who perform services for or on behalf of TEP or its affiliates, including TD. Vesting and forfeiture requirements are at the discretion of the board of directors of the general partner at the time of the grant.
	The LTIP limits the number of units that may be delivered pursuant to vested awards to 10,000,000 common units. Common units canceled, forfeited or withheld to satisfy exercise prices or tax withholding obligations will be available for delivery pursuant to other awards. The plan is administered by the board of directors of TEP’s general partner or a committee thereof, which is referred to as the plan administrator.
	The plan administrator may terminate or amend the LTIP at any time with respect to any units for which a grant has not yet been made. The plan administrator also has the right to alter or amend the LTIP or any part of the plan from time to time, including increasing the number of units that may be granted subject to the requirements of the exchange upon which the common units are listed at that time. However, no change in any outstanding grant may be made that would materially reduce the rights or benefits of the participant without the consent of the participant. The LTIP will expire on the earliest of (i) the date common units are no longer available under the plan for grants, (ii) termination of the plan by the plan administrator or (iii) May 13, 2023.
	Equity Participation Units
	On June 26, 2013, TEP’s general partner approved the grant of up to 1.5 million equity participation units (“EPUs”) for issuance to employees and 177,500 EPUs to certain Section 16 officers under the LTIP. Effective the same date, an aggregate of 1.49 million EPUs were granted to employees and certain Section 16 officers of the general partner and its affiliates. Vesting of the EPUs granted to employees is contingent upon the mainline portion of the Pony Express Project, as defined in Note 15 – Subsequent Events, being placed into service and will generally occur in two parts, with one-third vesting on the later of the Pony Express Project in-service date or May 13, 2015, and the remaining two-thirds vesting on the later of the Pony Express Project in-service date or May 13, 2017. If the Pony Express Project has not been placed in service by May 13, 2018, the EPUs will expire and no vesting of the EPUs will occur. Beginning in the second quarter of 2014, new EPUs granted will vest in two parts, with one-third vesting on the later of the Pony Express Project in-service date or two years from issuance, and the remaining two-thirds vesting on the later of the Pony Express Project in-service date or four years from issuance.
	The EPU grants under the LTIP plan are measured at their grant date fair value. The EPUs granted are non-participating with respect to distributions, therefore the grant date fair value is discounted from the grant date fair value of TEP’s common units for the present value of the expected future distributions during the vesting period. Total equity-based compensation cost related to the EPU grants of approximately $2.5 million and $4.7 million was recognized during the three and six months ended June 30, 2014. Of the total compensation cost, $1.3 million and $2.2 million was recognized as compensation expense at TEP for the three and six months ended June 30, 2014 and the remainder was allocated to TD. Total equity-based compensation cost related to the EPU grants of approximately $85,000 was recognized during the three and six months ended June 30, 2013. As of June 30, 2014, $17.9 million of total compensation cost related to non-vested EPUs is expected to be recognized over a weighted average period of 2.4 years, a portion of which will be charged to TD.
	The following table summarizes the changes in the EPUs outstanding for the three and six months ended June 30, 2014:
		Three Months Ended June 30, 2014					Three Months Ended June 30, 2013
		Shares		Weighted Average			Shares	Weighted Average
				Grant Date Fair Value				Grant Date Fair Value
	Beginning of period	1,486,750		$	17.67		—	$	—
	Granted	111,000		31.63			1,490,000	17.49
	Forfeited	(30,250	)	(17.62		)	—	—
	End of period	1,567,500		$	18.66		1,490,000	$	17.49
		Six Months Ended June 30, 2014					Six Months Ended June 30, 2013
		Shares		Weighted Average			Shares	Weighted Average
				Grant Date Fair Value				Grant Date Fair Value
	Beginning of period	1,474,250		$	17.54		—	$	—
	Granted	142,500		29.86			1,490,000	17.49
	Forfeited	(49,250	)	(17.57		)	—	—
	End of period	1,567,500		$	18.66		1,490,000	$	17.49

Regulatory_Matters

Regulatory Matters	6 Months Ended
	Jun. 30, 2014
Regulatory Matters [Abstract]	'
Regulatory Matters	'
	Regulatory Matters
	TIGT
	Pony Express Abandonment – FERC Docket CP12-495
	On August 6, 2012, TIGT filed an application to: (1) abandon for FERC purposes approximately 432 miles of mainline natural gas pipeline facilities, along with associated rights of way and other related equipment (collectively, the "Pony Express Assets"), and the natural gas service therefrom, by transferring those assets to Pony Express, which will convert the Pony Express Assets into crude oil pipeline facilities; and (2) construct and operate the Replacement Gas Facilities in order to continue service to existing natural gas firm transportation customers following the proposed conversion. This project is referred to as the “Pony Express Abandonment.” The FERC abandonment does not constitute an abandonment for accounting purposes. Pursuant to the terms of the Purchase and Sale Agreement filed with the FERC and cited by the FERC in approving the Pony Express Abandonment, Pony Express is required to reimburse TIGT for the net book value of the Pony Express Assets plus other TIGT incurred costs required to construct the Replacement Gas Facilities and to arrange substitute gas transportation services to certain TIGT shippers.
	The Pony Express Abandonment and completion of the Pony Express Project by Pony Express will re-deploy existing pipeline assets to meet the growing market need to transport oil supplies from the Bakken Shale while at the same time continuing to operate TIGT’s natural gas transportation facilities to meet all current and expected needs of its natural gas customers. By a FERC order issued September 12, 2013, TIGT was granted authorization to abandon the Pony Express Assets and construct the Replacement Gas Facilities. On October 7, 2013 TIGT commenced the mobilization of personnel and equipment for the construction of the Replacement Gas Facilities necessary to complete the Pony Express Abandonment to continue service to existing TIGT customers. In December 2013, TIGT removed the Pony Express Assets from gas service and sold those assets to Pony Express. Additional phases of the Pony Express Abandonment are expected to be completed during the third quarter of 2014. On May 1, 2014, TIGT commenced commercial service through all of the Replacement Gas Facilities, with the exception of Units 3 and 4 at the Tescott Compressor Station. Service through Units 3 and 4 at the Tescott Compressor Station commenced on May 30, 2014.
	Trailblazer
	2013 Rate Case Filing - Docket No. RP13-1031
	On July 1, 2013, Trailblazer made a rate filing with the FERC pursuant to Section 4 of the Natural Gas Act in Docket No. RP13-1031. In this filing, Trailblazer proposed an overall cost of service of $25.7 million, an increase of the base rates, rolled-in base and fuel rates, an overall rate of return of 10.94% and new depreciation rates. On July 31, 2013, the FERC issued an order accepting Trailblazer’s filing and suspending the filed tariff rates, subject to refund, for the full statutorily permitted five-month suspension period and setting certain issues for hearing. The FERC resolved the non-rate aspects of Trailblazer’s rate case in an order dated December 30, 2013.
	In conjunction with this filing for rolled-in fuel rates, Trailblazer elected to not seek recovery of unrecovered fuel costs incurred prior to January 1, 2014. Consequently, Trailblazer has recognized expenses related to unrecovered fuel costs of $578,000 for the period from November 13, 2012 to December 31, 2012, $6.0 million for period from January 1, 2012 to November 12, 2012 and $8.4 million during the year ended December 31, 2013.
	On January 22, 2014, Trailblazer, FERC’s Trial Staff, and the active parties in the pipeline’s general rate case finalized a settlement in principle resolving the pending rate issues, including: (i) establishing transportation rates, as well as fuel and lost and unaccounted for charges; (ii) providing a limited profit sharing arrangement for certain revenues earned from interruptible and short-term firm transport; and (iii) setting the minimum and maximum time that can elapse before Trailblazer’s next rate case at the FERC. Trailblazer filed a motion with the FERC’s Chief Administrative Law Judge to accept the settlement rates on an interim basis (“Interim Rates”) while the participants finalized a definitive settlement. The Chief Administrative Law Judge accepted the Interim Rates effective February 1, 2014. On February 24, 2014, Trailblazer filed an uncontested offer of settlement (“Stipulation and Agreement”) among active party shippers. The Stipulation and Agreement established the Interim Rates as final settlement rates effective February 1, 2014, subject to the issuance of refunds to certain shippers for January 2014 transportation services and revised fuel and lost and unaccounted for rates, effective July 1, 2014. On March 11, 2014, the Presiding Administrative Law Judge certified the Stipulation and Agreement. On May 29, 2014, the FERC approved the Stipulation and Agreement. On June 30, 2014, Trailblazer filed tariff sheets to implement the Stipulation and Agreement effective July 1, 2014. Estimated refunds have been reserved from revenues recorded in January 2014. On July 1, 2014, Trailblazer submitted refunds to its customers for amounts collected in excess of amounts that would have been collected under the Settlement Rates, with interest, and on July 18, 2014, filed a report of refunds with the FERC. On July 25, 2014, the FERC accepted the tariff sheets with the requested effective date of July 1, 2014.
	Other Regulatory Matters
	There are currently no proceedings challenging the rates of Trailblazer. Regulators, as well as shippers on Trailblazer, do have rights, under circumstances prescribed by applicable regulations, to challenge the rates Trailblazer charges. Trailblazer can provide no assurance that current rates will remain unchallenged. Any successful challenge could have a material, adverse effect on Trailblazer’s future earnings and cash flows.

Legal_and_Environmental_Matter

Legal and Environmental Matters	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Legal and Environmental Matters	'
	Legal and Environmental Matters
	Legal
	In addition to the matters discussed below, TEP is a defendant in various lawsuits arising from the day-to-day operations of its business. Although no assurance can be given, TEP believes, based on its experiences to date, that the ultimate resolution of such routine items will not have a material adverse impact on its business, financial position, results of operations or cash flows.
	TEP has evaluated claims in accordance with the accounting guidance for contingencies that it deems both probable and reasonably estimable and, accordingly, has aggregate reserves for legal claims of approximately $0.6 million and $0.3 million as of June 30, 2014 and December 31, 2013, respectively.
	TIGT
	Prairie Horizon
	On July 3, 2014, Prairie Horizon Agri-Energy LLC ("Prairie Horizon") filed an action in the District Court of Phillips County, Kansas against TIGT seeking damages from an alleged intrusion of foreign material and oil from TIGT into Prairie Horizon's ethanol plant. Prairie Horizon asserts that this intrusion caused substantial damage to Prairie Horizon's ethanol production facilities and resulted in corresponding business income losses. Prairie Horizon also claims that the intrusion was a violation of TIGT's FERC Gas Tariff. Prairie Horizon alleges that it has suffered damages in the amount of approximately $2.0 million. TIGT believes Prairie Horizon's claims are without merit and plans to vigorously contest all of the claims in this matter.
	System Failures
	On May 4, 2013 and on June 13, 2013, a failure occurred on two separate segments of the TIGT pipeline system; one in Kimball County, Nebraska and one in Goshen County, Wyoming. Both failures resulted in the release of natural gas. Both lines were promptly brought back into service and neither failure caused any known injuries, fatalities, fires or evacuations. The costs to repair or replace the damaged section in Kimball County, Nebraska were not material. In February 2014, TEP communicated to PHMSA that TEP’s investigation of the pipeline involved in the Kimball County failure is complete and TEP intends to restore pressure to full maximum allowable operating pressure. TEP is currently scheduled to start hydrostatic testing the pipeline related to the Goshen County failure in the third quarter of 2014 as required by the Corrective Action Order received from PHMSA. TEP currently expects the cost of remaining remediation activities related to the Goshen County failure to approximate $0.8 million.
	Environmental
	TEP is 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. TEP believes that compliance with these laws will not have a material adverse impact on its 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 TEP to incur significant costs. TEP has environmental accruals of $5.2 million and $5.0 million at June 30, 2014 and December 31, 2013, respectively.
	TMID
	Casper Plant, U.S. EPA Notice of Violation
	In August 2011, the U.S. EPA and the 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 U.S. 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 U.S. EPA concerning settlement of this matter in April 2013 and received an additional settlement communication from the U.S. EPA and Department of Justice in July 2014. Settlement negotiations are continuing, including attempted resolution of more recently identified LDAR issues.
	Casper Mystery Bridge Superfund Site
	The Casper Gas Plant is part of the Mystery Bridge Road/U.S. Highway 20 Superfund Site also known as Casper Mystery Bridge Superfund Site. Remediation work at the Casper Gas Plant has been completed and TEP has requested that the portion of the site attributable to TEP be delisted from the National Priorities List.

Reporting_Segments

Reporting Segments	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Reporting Segments	'
	Reporting Segments
	TEP’s operations are located in the United States and are organized into two reporting segments: (1) Gas Transportation and Storage, and (2) Processing.
	Gas Transportation and Storage
	The Gas Transportation and Storage segment is engaged in ownership and operation of FERC-regulated interstate natural gas pipelines and integrated natural gas storage facilities that provide services to on-system customers (such as third-party LDCs), industrial users and other shippers. As discussed in Note 2 – Summary of Significant Accounting Policies, results for prior periods have been recast to reflect the operations of Trailblazer.
	Processing
	The Processing segment is engaged in ownership and operation of natural gas processing, treating and fractionation facilities that produce NGLs and residue gas that is sold in local wholesale markets or delivered into pipelines for transportation to additional end markets, as well as water business services provided primarily to the oil and gas exploration and production industry.
	Corporate and Other
	Corporate and Other includes corporate overhead costs incurred subsequent to the IPO on May 17, 2013 that are not directly associated with the operations of TEP’s reportable segments, such as interest and fees associated with TEP’s revolving credit facility, public company costs reimbursed to TD, and equity-based compensation expense.
	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.
	TEP considers Adjusted EBITDA as its primary segment performance measure as TEP believes it is the most meaningful measure to assess TEP’s financial condition and results of operations as a public entity. Adjusted EBITDA, a non-GAAP measure, is defined 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.
	The following tables set forth TEP’s segment information for the periods indicated:
		Three Months Ended June 30, 2014								Three Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Revenue			Segment		Revenue			Revenue			Segment			Revenue
					(in thousands)								(in thousands)
	Gas transportation and storage	$	32,610		$	—	$	32,610		$	33,834		$	(199	)	$	33,635
	Processing	44,710			—		44,710			35,712			—			35,712
	Corporate and other	—			—		—			—			—			—
	Total revenue	$	77,320		$	—	$	77,320		$	69,546		$	(199	)	$	69,347
		Six Months Ended June 30, 2014								Six Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Revenue			Segment		Revenue			Revenue			Segment			Revenue
					(in thousands)								(in thousands)
	Gas transportation and storage	$	70,986		$	—	$	70,986		$	62,861		$	(370	)	$	62,491
	Processing	101,113			—		101,113			72,544			—			72,544
	Corporate and other	—			—		—			—			—			—
	Total revenue	$	172,099		$	—	$	172,099		$	135,405		$	(370	)	$	135,035
		Three Months Ended June 30, 2014								Three Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Adjusted			Segment		Adjusted			Adjusted			Segment			Adjusted
		EBITDA					EBITDA			EBITDA						EBITDA
		(in thousands)								(in thousands)
	Gas transportation and storage	$	15,066		$	—	$	15,066		$	11,434		$	(199	)	$	11,235
	Processing	5,511			—		5,511			5,236			199			5,435
	Corporate and other	(625		)	—		(625		)	(307		)	—			(307		)
	Reconciliation to Net Income:
	Interest expense, net						2,140									3,495
	Depreciation and amortization expense						8,622									9,332
	Loss on extinguishment of debt						—									17,526
	Non-cash gain related to derivative instruments						(96		)							(848		)
	Non-cash compensation expense						1,308									85
	Distributions from unconsolidated investment						772									—
	Equity in earnings of unconsolidated investment						(273		)							—
	Gain on remeasurement of unconsolidated investment						(9,388		)							—
	Net Income (Loss)						$	16,867								$	(13,227	)
		Six Months Ended June 30, 2014								Six Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Adjusted			Segment		Adjusted			Adjusted			Segment			Adjusted
		EBITDA					EBITDA			EBITDA						EBITDA
		(in thousands)								(in thousands)
	Gas transportation and storage	$	34,928		$	—	$	34,928		$	24,941		$	(370	)	$	24,571
	Processing	15,107			—		15,107			12,070			370			12,440
	Corporate and other	(1,250		)	—		(1,250		)	(307		)	—			(307		)
	Reconciliation to Net Income:
	Interest expense, net						3,433									9,059
	Depreciation and amortization expense						16,174									18,722
	Loss on extinguishment of debt						—									17,526
	Non-cash loss related to derivative instruments						255									71
	Non-cash compensation expense						2,249									85
	Distributions from unconsolidated investment						1,280									—
	Equity in earnings of unconsolidated investment						(717		)							—
	Gain on remeasurement of unconsolidated investment						(9,388		)							—
	Net Income (Loss)						$	35,499								$	(8,759	)
	Total Assets
	30-Jun-14			31-Dec-13
	(in thousands)
Gas transportation and storage	$	717,695		$	734,145
Processing	344,064			326,599
Corporate and other	5,556			4,513
Total assets	$	1,067,315		$	1,065,257

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Prairie Horizon
	On July 3, 2014, Prairie Horizon filed an action in the District Court of Phillips County, Kansas against TIGT seeking damages from an alleged intrusion of foreign material and oil from TIGT into Prairie Horizon's ethanol plant. For additional information, see Note 13 – Legal and Environmental Matters.
	Potential Acquisition
	On July 21, 2014, TEP announced that TD offered TEP the right to purchase a 33.3% interest in Tallgrass Pony Express Pipeline, LLC ("Pony Express") for total consideration of $600 million. The terms of TD's offer provide that TEP's 33.3% equity interest would be structured as preferred units in Pony Express bearing certain cash flow preference rights that will afford TEP first dollar preference on specified cash distributions supported by cash flow occurring on or before September 30, 2015.
	Pony Express owns and is developing an oil pipeline project, which we collectively refer to as the Pony Express Project. That project consists of two components that include (i) the conversion of an approximately 430-mile natural gas pipeline and the construction of an approximately 260-mile southward pipeline extension that, when complete, will result in an oil pipeline from Guernsey, Wyoming to Cushing, Oklahoma, and (ii) the construction of an approximately 66-mile lateral in Northeast Colorado that will interconnect with the mainline. The project is being completed in stages, with the mainline expected to be placed in service during the third quarter of 2014, while the Northeast Colorado lateral is expected to be in service sometime during the first half of 2015.
	The offer was received from TD pursuant to a right of first offer that is contained in the Omnibus Agreement that was executed between TEP and TD in connection with TEP’s initial public offering in May 2013. A Conflicts Committee of the Board of Directors of TEP’s general partner, consisting solely of independent directors, has been formed and will be evaluating the offer with assistance from external advisors to be engaged by the Committee. No definitive transaction agreement has been executed at this time and the proposed transaction remains subject to final review, negotiations and approval by the Conflicts Committee and by the board of directors of TEP’s general partner.
	Public Offering
	On July 25, 2014, TEP sold 8,050,000 common units representing limited partner interests in an underwritten public offering at a price of $41.07 per unit, or $39.74 per unit net of the underwriter's discount, for net proceeds of approximately $319.5 million after deducting the underwriter's discount and estimated offering expenses payable by TEP. TEP intends to use the net proceeds from the offering to fund a portion of the consideration for the potential acquisition from a subsidiary of TD of the 33.3% interest in Pony Express as discussed above. Pending the use of proceeds for such purpose, TEP used the net proceeds of the offering to repay borrowings under TEP’s revolving credit facility with the excess to be used for general partnership purposes.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	These unaudited condensed consolidated financial statements and related notes for the three and six months ended June 30, 2014 and 2013 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of generally accepted accounting principles 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 disclosures required by GAAP for annual periods. The unaudited condensed consolidated financial statements for the three and six months ended June 30, 2014 and 2013 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair presentation 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. Certain prior period amounts have been reclassified to conform to the current presentation.
Consolidation	'
	TEP’s financial results for the three and six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014. These unaudited condensed consolidated financial statements should be read in conjunction with TEP’s audited consolidated financial statements and notes thereto included in its Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”) filed with the United States Securities and Exchange Commission (the “SEC”) on March 11, 2014.
	The accompanying consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to TEP by TD in connection with the IPO, for the periods prior to May 17, 2013, the closing date of TEP’s IPO, as well as Trailblazer for the periods prior to April 1, 2014, the date TEP acquired Trailblazer from TD, and include charges from TD for direct costs and allocations of indirect corporate overhead. Management believes that the allocation methods are reasonable, and that the allocations are representative of costs that would have been incurred on a stand-alone basis. Both TEP and TEP Predecessor are considered “entities under common control” as defined under GAAP and, as such, the transfers between the entities of the assets and liabilities has been recorded by TEP at historical cost. TEP, or the Partnership, as used herein refers to the consolidated financial results and operations for TEP Predecessor from its inception through its contribution to TEP and thereafter.
	As further discussed in Note 3 – Business Combinations, TEP closed the acquisition of Trailblazer on April 1, 2014. As the acquisition of Trailblazer is considered a transaction between entities under common control, and a change in reporting entity, the financial information presented for prior periods has been recast to include Trailblazer for all periods presented.
	The condensed consolidated financial statements include the accounts of TEP and its subsidiaries. Significant intra-entity items have been eliminated in the presentation. Net equity distributions of the TEP Predecessor and the Predecessor Entity included in the Consolidated Statements of Cash Flows represent transfers of cash as a result of TD’s centralized cash management systems prior to May 17, 2013, and prior to April 1, 2014 for Trailblazer, under which cash balances were swept daily and recorded as loans from the subsidiaries to TD. These loans were then periodically recorded as equity distributions.
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 TEP’s 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.
Accounting Pronouncements Issued But Not Yet Effective	'
	Accounting Pronouncements Issued But Not Yet Effective
	Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers (Topic 606)”
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 provides a comprehensive and converged set of principles-based revenue recognition guidelines which supersede the existing industry and transaction-specific standards. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve this core principle, entities must apply a five step process to (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 also mandates disclosure of sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The disclosure requirements include qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract.
	The amendments in ASU 2014-09 are effective for public entities for annual reporting periods beginning after December 15, 2016, and for interim periods within that reporting period. Early application is not permitted. The adoption of ASU 2014-09 is not expected to have a material impact on TEP's financial position and results of operations.
	ASU No. 2014-12, "Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period"
	In June 2014, The FASB issued ASU No. 2014-12, Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 provides explicit guidance on accounting for share-based payments requiring a specific performance target to be achieved in order for employees to become eligible to vest in the awards when that performance target may be achieved after the requisite service period for the award. The ASU requires that such performance targets be treated as a performance condition, and should not be reflected in the estimate of the grant-date fair value of the award. Instead, compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved. ASU 2014-12 is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The adoption of ASU 2014-12 is not expected to have a material impact on TEP's financial position and results of operations.

Business_Combinations_Tables

Business Combinations (Tables)	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Impact of Adjustments Related to Transaction Among Entities Under Common Control, Balance Sheet	'
	The results of our acquisition of Trailblazer are included in the consolidated balance sheets as of June 30, 2014 and December 31, 2013. The following table presents the previously reported December 31, 2013 consolidated balance sheet, adjusted for the acquisition of Trailblazer from TD:
			As of December 31, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
	ASSETS
	Current Assets:
	Accounts receivable, net		$	27,615			$	2,418			$	30,033
	Gas imbalances		2,598				530				3,128
	Inventories		5,148				401				5,549
	Prepayments and other current assets		16,986				—				16,986
	Total Current Assets		52,347				3,349				55,696
	Property, plant and equipment, net		594,911				62,869				657,780
	Goodwill		304,474				30,241				334,715
	Unconsolidated investment		1,255				—				1,255
	Deferred financing costs		4,512				—				4,512
	Deferred charges and other assets		10,299				1,000				11,299
	Total Assets		$	967,798			$	97,459			$	1,065,257
	LIABILITIES AND PARTNERS’ EQUITY
	Current Liabilities:
	Accounts payable		$	54,621			$	5,619			$	60,240
	Accounts payable to related parties		7,134				3				7,137
	Gas imbalances		3,142				522				3,664
	Derivative liabilities at fair value		184				—				184
	Accrued taxes		4,427				1,093				5,520
	Accrued other current liabilities		14,777				1,971				16,748
	Total Current Liabilities		84,285				9,208				93,493
	Long-term debt		135,000				—				135,000
	Other long-term liabilities and deferred credits		4,572				—				4,572
	Total Long-term Liabilities		139,572				—				139,572
	Partners’ Equity:
	Net Equity		743,941				88,251				832,192
	Total Partners’ Equity		743,941				88,251				832,192
	Total Liabilities and Partners’ Equity		$	967,798			$	97,459			$	1,065,257
Impact of Adjustments Related to Transaction Among Entities Under Common Control, Income Statement	'
	The results of our acquisition of Trailblazer are included in the condensed consolidated statements of income for the three and six months ended June 30, 2014 and 2013. The following tables present the previously reported condensed consolidated statements of income for the three and six months ended June 30, 2013, adjusted for the acquisition of Trailblazer from TD:
			Three Months Ended June 30, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
	Revenues:
	Natural gas liquids sales		$	31,690			$	—			$	31,690
	Natural gas sales		3,888				360				4,248
	Transportation services		25,324				5,585				30,909
	Processing and other revenues		2,500				—				2,500
	Total Revenues		63,402				5,945				69,347
	Operating Costs and Expenses:
	Cost of sales and transportation services		32,358				2,899				35,257
	Operations and maintenance		8,305				924				9,229
	Depreciation and amortization		7,436				1,896				9,332
	General and administrative		5,039				1,478				6,517
	Taxes, other than income taxes		1,394				269				1,663
	Total Operating Costs and Expenses		54,532				7,466				61,998
	Operating Income (Loss)		8,870				(1,521		)		7,349
	Other (Expense) Income:
	Interest (expense) income, net		(3,500		)		5				(3,495		)
	Loss on extinguishment of debt		(17,526		)		—				(17,526		)
	Other income, net		429				16				445
	Total Other (Expense) Income		(20,597		)		21				(20,576		)
	Net Loss		$	(11,727	)		$	(1,500	)		$	(13,227	)
			Six Months Ended June 30, 2013
			TEP				Consolidate Trailblazer Pipeline Company LLC				TEP (as currently reported)
			(in thousands)
	Revenues:
	Natural gas liquids sales		$	65,091			$	—			$	65,091
	Natural gas sales		4,189				509				4,698
	Transportation services		49,661				10,866				60,527
	Processing and other revenues		4,719				—				4,719
	Total Revenues		123,660				11,375				135,035
	Operating Costs and Expenses:
	Cost of sales and transportation services		61,828				4,615				66,443
	Operations and maintenance		14,840				1,752				16,592
	Depreciation and amortization		14,982				3,740				18,722
	General and administrative		9,673				2,871				12,544
	Taxes, other than income taxes		3,171				538				3,709
	Total Operating Costs and Expenses		104,494				13,516				118,010
	Operating Income (Loss)		19,166				(2,141		)		17,025
	Other (Expense) Income:
	Interest (expense) income, net		(9,064		)		5				(9,059		)
	Loss on extinguishment of debt		(17,526		)		—				(17,526		)
	Other income, net		768				33				801
	Total Other (Expense) Income		(25,822		)		38				(25,784		)
	Net Loss		$	(6,656	)		$	(2,103	)		$	(8,759	)
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The following represents the fair value of assets acquired and liabilities assumed at May 13, 2014:
	Accounts receivable	$	790
	Property, plant and equipment	4,100
	Intangible assets	8,200			(1)
	Accounts payable and accrued liabilities	(134		)
	Distribution payable	(634		)
	Net identifiable assets acquired	12,322
	Goodwill	8,573
	Net assets acquired	$	20,895
	(1)	The $8.2 million intangible asset acquired represents a major customer contract and is subject to amortization over the remaining contract term (approximately 1.6 years). Amortization of $0.7 million was recorded during the period from May 13, 2014 to June 30, 2014.
Business Acquisition, Pro Forma Information	'
	Pro Forma revenue and net income attributable to TEP for the three and six months ended June 30, 2014 is presented in the following table. No pro forma information is presented for the three and six months ended June 30, 2013 as Water Solutions did not begin commercial operations until the first quarter of 2014.
		Three Months Ended June 30, 2014				Six Months Ended June 30, 2014
		(in thousands)
	Revenue	$	78,084			$	174,540
	Net income attributable to TEP	$	7,642			$	26,541
Schedule of Goodwill	'
	The following table presents a reconciliation of the carrying amount of goodwill by reportable segment for the reporting period:
		Three Months Ended June 30, 2014												Three Months Ended June 30, 2013
		Gas Transportation and storage				Processing				Total				Gas Transportation and storage		Processing		Total
						(in thousands)										(in thousands)
	Balance at beginning of period	$	255,558			$	79,157			$	334,715			$	255,100	$	78,057	$	333,157
	Goodwill acquired	—				8,573			(1)	8,573				—		—		—
	Balance at end of period	$	255,558			$	87,730			$	343,288			$	255,100	$	78,057	$	333,157
		Six Months Ended June 30, 2014												Six Months Ended June 30, 2013
		Gas Transportation and storage				Processing				Total				Gas Transportation and storage		Processing		Total
						(in thousands)										(in thousands)
	Balance at beginning of period	$	255,558			$	79,157			$	334,715			$	255,100	$	78,057	$	333,157
	Goodwill acquired	—				8,573			(1)	8,573				—		—		—
	Balance at end of period	$	255,558			$	87,730			$	343,288			$	255,100	$	78,057	$	333,157
	(1)    The $8.6 million of goodwill was recorded in connection with the acquisition of a controlling interest in Water Solutions on May 13, 2014.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Transactions with Affiliated Companies	'
	Totals of transactions with affiliated companies are as follows:
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
		(in thousands)
	Charges to TEP: (1)
	Operation and maintenance	$	4,608	$	4,597	$	8,956	$	8,716
	General and administrative (2)	$	4,305	$	6,247	$	8,887	$	12,200
	(1)	Charges to TEP include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three and six months ended June 30, 2014 and 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in allocated amounts for general and administrative costs.
Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets	'
	There were no balances with affiliates included in "Accounts receivable" in the Condensed Consolidated Balance Sheets at June 30, 2014 and December 31, 2013. Details of balances with affiliates included in “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
		30-Jun-14		31-Dec-13
		(in thousands)
	Payables to affiliated companies:
	Accounts payable to Tallgrass Operations, LLC	$	3,921	$	7,106
	Accounts payable to Rockies Express Pipeline LLC	42		31
	Total payables to affiliated companies	$	3,963	$	7,137
Schedule of Balances of Gas Imbalance with Affiliated Shippers	'
	Balances of gas imbalances with affiliated shippers are as follows:
		30-Jun-14		31-Dec-13
		(in thousands)
	Affiliate gas balance receivables	$	—	$	137
	Affiliate gas balance payables	$	803	$	122

Inventory_Tables

Inventory (Tables)	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Schedule of Components of Inventory	'
	The components of inventory at June 30, 2014 and December 31, 2013 consisted of the following:
		30-Jun-14		31-Dec-13
		(in thousands)
	Materials and supplies	$	2,187	$	2,137
	Natural gas liquids	1,210		1,009
	Gas in underground storage	4,725		2,403
	Total inventory	$	8,122	$	5,549

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
Components of Property Plant and Equipment	'
	A summary of net property, plant and equipment by classification is as follows:
		30-Jun-14			31-Dec-13
		(in thousands)
	Natural gas pipelines	$	419,409		$	397,287
	Processing and treating assets	237,964			209,329
	General and other	30,606			26,076
	Construction work in progress	7,843			47,352
	Accumulated depreciation and amortization	(35,571		)	(22,264		)
	Total property, plant and equipment, net	$	660,251		$	657,780

Risk_Management_Tables

Risk Management (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Fair Value of Derivative Contracts	'
	The following table summarizes the fair values of TEP’s derivative contracts included in the accompanying Condensed Consolidated Balance Sheets:
		Balance Sheet		30-Jun-14				31-Dec-13
		Location
				(in thousands)
	Energy commodity derivative contracts	Current liabilities		$	439			$	184
Derivative Contracts Included in Consolidated Statements of Income	'
	The following table summarizes the impact of derivative contracts included in the accompanying Condensed Consolidated Statements of Income and Comprehensive Income for the three and six months ended June 30, 2014 and 2013:
		Location of		Amount of gain (loss) recognized in income on derivatives
		gain (loss) recognized
		in income on		Three Months Ended June 30,								Six Months Ended June 30,
		derivatives		2014				2013				2014				2013
				(in thousands)
	Derivatives not designated as hedging contracts:
	Energy commodity derivative contracts	Natural gas sales		$	(106	)		$	635			$	(458	)		$	(284	)
Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification	'
	The following tables summarize the fair value measurements of TEP’s energy commodity derivative contracts in a liability position as of June 30, 2014 and December 31, 2013 based on the fair value hierarchy established by the Codification:
						Liability fair value measurements using
		Total				Quoted prices in				Significant				Significant
						active markets				other observable				unobservable
						for identical				inputs				inputs
						assets				(Level 2)				(Level 3)
						(Level 1)
		(in thousands)
	TEP as of June 30, 2014
	Energy commodity derivative contracts	$	439			$	—			$	439			$	—
	TEP as of December 31, 2013
	Energy commodity derivative contracts	$	184			$	—			$	184			$	—

Longterm_Debt_Tables

Long-term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of Line of Credit Facilities	'
	The following table sets forth the outstanding borrowings, letters of credit issued, and available borrowing capacity under the revolving credit facility as of June 30, 2014 and December 31, 2013:
		30-Jun-14			31-Dec-13
		(in thousands)
	Total capacity under the revolving credit facility	$	850,000		$	500,000
	Less: Outstanding borrowings under the revolving credit facility	(281,000		)	(135,000		)
	Less: Letters of credit issued under the revolving credit facility	—			(654		)
	Available capacity under the revolving credit facility	$	569,000		$	364,346
Carrying Amount and Fair value of TEP's Long-term Debt	'
	The following table sets forth the carrying amount and fair value of TEP’s long-term debt, which is not measured at fair value in the Condensed Consolidated Balance Sheets as of June 30, 2014 and December 31, 2013, but for which fair value is disclosed:
		Fair Value
		Quoted prices			Significant			Significant		Total		Carrying
		in active markets			other observable			unobservable				Amount
		for identical assets			inputs			inputs
		(Level 1)			(Level 2)			(Level 3)
		(in thousands)
	June 30, 2014	$	—		$	281,000		$	—	$	281,000	$	281,000
	December 31, 2013	$	—		$	135,000		$	—	$	135,000	$	135,000

Partnership_Equity_and_Distrib1

Partnership Equity and Distributions (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Summary of Distributions	'
	The following table shows the distributions for the year ended 2013 and six months ended June 30, 2014:
				Distributions
				Limited Partners		General Partner						Distributions
				Common and								per Limited
	Three Months Ended		Date Paid	Subordinated		Incentive		2%		Total		Partner Unit
				(in thousands, except per unit amounts)
	30-Jun-14		August 14, 2014 (1)	$	18,596	$	758	$	330	$	19,684	$	0.38
	March 31, 2014		May 14, 2014	13,288		126		274		13,688		0.325
	December 31, 2013		February 12, 2014	12,757		63		262		13,082		0.315
	September 30, 2013		November 13, 2013	12,049		—		245		12,294		0.2975
	June 30, 2013		August 13, 2013	5,759		—		118		5,877		0.1422		(2)
	(1)	The distribution declared on July 1, 2014 for the second quarter of 2014 is expected to be paid August 14, 2014 subsequent to the date of this Quarterly Report on 48,935,140 common units and subordinated units of record at the close of business on July 30, 2014.
	(2)	The distribution declared on July 18, 2013 for the second quarter of 2013 represented a prorated amount of the MQD of $0.2875 per common unit, based upon the number of days between the closing of the IPO on May 17, 2013 to June 30, 2013.

Net_Income_per_Limited_Partner1

Net Income per Limited Partner Unit (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Summary of Net Income Per Limited Partner Unit	'
	The following table illustrates the Partnership’s calculation of net income per common and subordinated unit for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended June 30, 2014			Three Months Ended June 30, 2013			Period from April 1, 2013 to May 16, 2013			Period from May 17, 2013 to June 30, 2013
		(in thousands, except per unit amounts)
	Net income (loss)	$	16,812		$	(13,227	)	$	1,722		$	(14,949	)
	Net loss attributable to noncontrolling interests	55			—			—			—
	Net income (loss) attributable to partners	16,867			(13,227		)	1,722			(14,949		)
	Predecessor operations interest in net loss	—			1,500			189			1,311
	General partner interest in net (income) loss	(1,096		)	(1,638		)	(1,911		)	273
	Net income (loss) available to common and subordinated unitholders	$	15,771		$	(13,365	)	$	—		$	(13,365	)
	Basic net income (loss) per common and subordinated unit	$	0.39		$	(0.33	)				$	(0.33	)
	Diluted net income (loss) per common and subordinated unit	$	0.38		$	(0.33	)				$	(0.33	)
	Basic average number of common and subordinated units outstanding	40,885			40,246						40,246
	Equity Participation Unit equivalent units	1,020			—						—
	Diluted average number of common and subordinated units outstanding	41,905			40,246						40,246
		Six Months Ended June 30, 2014			Six Months Ended June 30, 2013			Period from January 1, 2013 to May 16, 2013			Period from May 17, 2013 to June 30, 2013
		(in thousands, except per unit amounts)
	Net income (loss)	$	35,444		$	(8,759	)	$	6,190		$	(14,949	)
	Net loss attributable to noncontrolling interests	55			—			—			—
	Net income (loss) attributable to partners	35,499			(8,759		)	6,190			(14,949		)
	Predecessor operations interest in net (income) loss	(5,732		)	2,103			792			1,311
	General partner interest in net (income) loss	(1,477		)	(6,709		)	(6,982		)	273
	Net income (loss) available to common and subordinated unitholders	$	28,290		$	(13,365	)	$	—		$	(13,365	)
	Basic net income (loss) per common and subordinated unit	$	0.7		$	(0.33	)				$	(0.33	)
	Diluted net income (loss) per common and subordinated unit	$	0.68		$	(0.33	)				$	(0.33	)
	Basic average number of common and subordinated units outstanding	40,694			40,246						40,246
	Equity Participation Unit equivalent units	930			—						—
	Diluted average number of common and subordinated units outstanding	41,624			40,246						40,246

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summarizes Changes in EPUs Outstanding	'
	The following table summarizes the changes in the EPUs outstanding for the three and six months ended June 30, 2014:
		Three Months Ended June 30, 2014					Three Months Ended June 30, 2013
		Shares		Weighted Average			Shares	Weighted Average
				Grant Date Fair Value				Grant Date Fair Value
	Beginning of period	1,486,750		$	17.67		—	$	—
	Granted	111,000		31.63			1,490,000	17.49
	Forfeited	(30,250	)	(17.62		)	—	—
	End of period	1,567,500		$	18.66		1,490,000	$	17.49
		Six Months Ended June 30, 2014					Six Months Ended June 30, 2013
		Shares		Weighted Average			Shares	Weighted Average
				Grant Date Fair Value				Grant Date Fair Value
	Beginning of period	1,474,250		$	17.54		—	$	—
	Granted	142,500		29.86			1,490,000	17.49
	Forfeited	(49,250	)	(17.57		)	—	—
	End of period	1,567,500		$	18.66		1,490,000	$	17.49

Reporting_Segments_Tables

Reporting Segments (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Summary of TEP's Segment Information of Revenue	'
		Six Months Ended June 30, 2014								Six Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Revenue			Segment		Revenue			Revenue			Segment			Revenue
					(in thousands)								(in thousands)
	Gas transportation and storage	$	70,986		$	—	$	70,986		$	62,861		$	(370	)	$	62,491
	Processing	101,113			—		101,113			72,544			—			72,544
	Corporate and other	—			—		—			—			—			—
	Total revenue	$	172,099		$	—	$	172,099		$	135,405		$	(370	)	$	135,035
	The following tables set forth TEP’s segment information for the periods indicated:
		Three Months Ended June 30, 2014								Three Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Revenue			Segment		Revenue			Revenue			Segment			Revenue
					(in thousands)								(in thousands)
	Gas transportation and storage	$	32,610		$	—	$	32,610		$	33,834		$	(199	)	$	33,635
	Processing	44,710			—		44,710			35,712			—			35,712
	Corporate and other	—			—		—			—			—			—
	Total revenue	$	77,320		$	—	$	77,320		$	69,546		$	(199	)	$	69,347
Summary of TEP's Segment Information of Earnings	'
		Six Months Ended June 30, 2014								Six Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Adjusted			Segment		Adjusted			Adjusted			Segment			Adjusted
		EBITDA					EBITDA			EBITDA						EBITDA
		(in thousands)								(in thousands)
	Gas transportation and storage	$	34,928		$	—	$	34,928		$	24,941		$	(370	)	$	24,571
	Processing	15,107			—		15,107			12,070			370			12,440
	Corporate and other	(1,250		)	—		(1,250		)	(307		)	—			(307		)
	Reconciliation to Net Income:
	Interest expense, net						3,433									9,059
	Depreciation and amortization expense						16,174									18,722
	Loss on extinguishment of debt						—									17,526
	Non-cash loss related to derivative instruments						255									71
	Non-cash compensation expense						2,249									85
	Distributions from unconsolidated investment						1,280									—
	Equity in earnings of unconsolidated investment						(717		)							—
	Gain on remeasurement of unconsolidated investment						(9,388		)							—
	Net Income (Loss)						$	35,499								$	(8,759	)
		Three Months Ended June 30, 2014								Three Months Ended June 30, 2013
		Total			Inter-		External			Total			Inter-			External
		Adjusted			Segment		Adjusted			Adjusted			Segment			Adjusted
		EBITDA					EBITDA			EBITDA						EBITDA
		(in thousands)								(in thousands)
	Gas transportation and storage	$	15,066		$	—	$	15,066		$	11,434		$	(199	)	$	11,235
	Processing	5,511			—		5,511			5,236			199			5,435
	Corporate and other	(625		)	—		(625		)	(307		)	—			(307		)
	Reconciliation to Net Income:
	Interest expense, net						2,140									3,495
	Depreciation and amortization expense						8,622									9,332
	Loss on extinguishment of debt						—									17,526
	Non-cash gain related to derivative instruments						(96		)							(848		)
	Non-cash compensation expense						1,308									85
	Distributions from unconsolidated investment						772									—
	Equity in earnings of unconsolidated investment						(273		)							—
	Gain on remeasurement of unconsolidated investment						(9,388		)							—
	Net Income (Loss)						$	16,867								$	(13,227	)
Summary of TEP's Segment Information of Assets	'
		Total Assets
		30-Jun-14			31-Dec-13
		(in thousands)
	Gas transportation and storage	$	717,695		$	734,145
	Processing	344,064			326,599
	Corporate and other	5,556			4,513
	Total assets	$	1,067,315		$	1,065,257

Description_of_Business_Additi

Description of Business - Additional Information (Detail)	6 Months Ended				6 Months Ended		0 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	17-May-13	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jul. 25, 2014
				Predecessor [Member]	Ownership Interests Held By Public [Member]	Ownership Interests Held By TD [Member]	Subsequent Event [Member]
				mi			Ownership Interests Held By Public [Member]
Organization [Line Items]	'	'	'	'	'	'	'
Initial public offering of common units	'	'	'	'	14,600,000	'	8,050,000
Aggregate outstanding common and subordinated units	'	'	'	'	36.00%	64.00%	'
Aggregate outstanding common, subordinated and general partner units	'	'	'	'	35.00%	63.00%	'
Common and subordinated units issued, units	'	'	'	'	'	10,085,140	'
Subordinated unit	'	'	'	'	'	16,200,000	'
General partner units issued	834,391	826,531	826,531	'	'	'	'
General partner interest in TEP	2.00%	'	'	'	'	'	'
Gas transmission lines owned	'	'	'	4,645	'	'	'
Number of gas treatment plants	1	'	'	'	'	'	'
Number of Gas Processing Plants	2	'	'	'	'	'	'

Business_Combinations_Details

Business Combinations (Details) (USD $)

0 Months Ended

2 Months Ended

1 Months Ended

3 Months Ended

4 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

13-May-14

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

16-May-13

Jun. 30, 2014

Jun. 30, 2013

16-May-13

Jun. 30, 2014

Jun. 30, 2013

13-May-14

Dec. 31, 2013

17-May-13

Apr. 01, 2014

Jun. 30, 2013

Jun. 30, 2013

Apr. 30, 2014

Apr. 01, 2014

Jun. 30, 2013

Jun. 30, 2013

13-May-14

13-May-14

Dec. 31, 2013

13-May-14

Jun. 30, 2014

13-May-14

13-May-14

13-May-14

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Tallgrass Energy Partners [Member]

Tallgrass Energy Partners [Member]

Grasslands Water Services I, LLC [Member]

Grasslands Water Services I, LLC [Member]

Grasslands Water Services I, LLC [Member]

BNN Water Solutions [Member]

BNN Water Solutions [Member]

BNN Water Solutions [Member]

BNN Energy LLC [Member]

BNN Energy LLC [Member]

Grasslands Water Services I, LLC [Member]

Alpha Reclaim Technology, LLC [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Date of acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Apr-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration

'

'

'

'

'

'

'

'

'

'

'

'

'

$164,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase consideration in cash

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

7,600,000

'

'

'

'

Common and subordinated units issued, units

'

'

'

'

'

'

'

'

'

'

'

'

'

385,140

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common unit, issuance value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14,000,000

'

'

'

'

'

'

'

'

'

'

General Partners' contributed capital

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

263,000

'

'

'

'

'

'

'

'

'

'

General partner units issued

'

834,391

834,391

'

'

834,391

'

'

834,391

'

'

826,531

826,531

'

'

'

7,860

7,860

'

'

'

'

'

'

'

'

'

'

General Partners capital account partnership interest percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity interest ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

Equity interest transferred as part of acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

50.00%

100.00%

Equity interest acquired

'

'

'

'

'

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80.00%

'

'

Acquisition fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,900,000

'

'

'

'

'

'

'

Gain on remeasurement of unconsolidated investment

'

'

'

'

'

9,388,000

0

'

9,388,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,388,000

'

'

'

Equity interest held by noncontrolling interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20.00%

'

'

Acquisition, noncontrolling interest, fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,400,000

'

'

Intangible asset, net

'

7,495,000

7,495,000

'

'

7,495,000

'

'

7,495,000

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

8,200,000

[1]

'

'

Amortization period

'1 year 7 months 6 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization expense

'

'

700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

900,000

'

'

'

77,320,000

69,347,000

'

172,099,000

135,035,000

'

'

'

'

5,945,000

11,375,000

'

'

63,402,000

123,660,000

'

'

'

'

'

'

'

'

Net Income

'

($200,000)

'

($14,949,000)

$1,722,000

$16,867,000

($13,227,000)

$6,190,000

$35,499,000

($8,759,000)

'

'

'

'

($1,500,000)

($2,103,000)

'

'

($11,727,000)

($6,656,000)

'

'

'

'

'

'

'

'

[1]

The $8.2 million intangible asset acquired represents a major customer contract and is subject to amortization over the remaining contract term (approximately 1.6 years). Amortization of $0.7 million was recorded during the period from May 13, 2014 to June 30, 2014.

Business_Combinations_Impact_o

Business Combinations Impact of Acquisition, Balance Sheet (Details) (USD $)	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Business Acquisition [Line Items]	'	'	'	'	'	'
Accounts receivable, net	$27,698	'	$30,033	'	'	'
Gas imbalances	1,336	'	3,128	'	'	'
Inventories	8,122	'	5,549	'	'	'
Prepayments and other current assets	1,788	'	16,986	'	'	'
Total Current Assets	38,960	'	55,696	'	'	'
Property, plant and equipment, net	660,251	'	657,780	'	'	'
Goodwill	343,288	334,715	334,715	333,157	333,157	333,157
Unconsolidated investment	0	'	1,255	'	'	'
Deferred financing costs	6,273	'	4,512	'	'	'
Deferred charges and other assets	11,048	'	11,299	'	'	'
Total Assets	1,067,315	'	1,065,257	'	'	'
Accounts payable	27,940	'	60,240	'	'	'
Accounts payable to related parties	3,963	'	7,137	'	'	'
Gas imbalances	4,407	'	3,664	'	'	'
Derivative liabilities at fair value	439	'	184	'	'	'
Accrued taxes	3,871	'	5,520	'	'	'
Accrued other current liabilities	16,988	'	16,748	'	'	'
Total Current Liabilities	57,608	'	93,493	'	'	'
Long-term debt	281,000	'	135,000	'	'	'
Other long-term liabilities and deferred credits	6,933	'	4,572	'	'	'
Total Long-term Liabilities	287,933	'	139,572	'	'	'
Partners' Capital	720,429	'	832,192	'	'	'
Total Liabilities and Equity	1,067,315	'	1,065,257	'	'	'
Trailblazer Pipeline Company LLC [Member]	'	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'	'
Accounts receivable, net	'	'	2,418	'	'	'
Gas imbalances	'	'	530	'	'	'
Inventories	'	'	401	'	'	'
Prepayments and other current assets	'	'	0	'	'	'
Total Current Assets	'	'	3,349	'	'	'
Property, plant and equipment, net	'	'	62,869	'	'	'
Goodwill	'	'	30,241	'	'	'
Unconsolidated investment	'	'	0	'	'	'
Deferred financing costs	'	'	0	'	'	'
Deferred charges and other assets	'	'	1,000	'	'	'
Total Assets	'	'	97,459	'	'	'
Accounts payable	'	'	5,619	'	'	'
Accounts payable to related parties	'	'	3	'	'	'
Gas imbalances	'	'	522	'	'	'
Derivative liabilities at fair value	'	'	0	'	'	'
Accrued taxes	'	'	1,093	'	'	'
Accrued other current liabilities	'	'	1,971	'	'	'
Total Current Liabilities	'	'	9,208	'	'	'
Long-term debt	'	'	0	'	'	'
Other long-term liabilities and deferred credits	'	'	0	'	'	'
Total Long-term Liabilities	'	'	0	'	'	'
Partners' Capital	'	'	88,251	'	'	'
Total Liabilities and Equity	'	'	97,459	'	'	'
Tallgrass Energy Partners [Member]	'	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'	'
Accounts receivable, net	'	'	27,615	'	'	'
Gas imbalances	'	'	2,598	'	'	'
Inventories	'	'	5,148	'	'	'
Prepayments and other current assets	'	'	16,986	'	'	'
Total Current Assets	'	'	52,347	'	'	'
Property, plant and equipment, net	'	'	594,911	'	'	'
Goodwill	'	'	304,474	'	'	'
Unconsolidated investment	'	'	1,255	'	'	'
Deferred financing costs	'	'	4,512	'	'	'
Deferred charges and other assets	'	'	10,299	'	'	'
Total Assets	'	'	967,798	'	'	'
Accounts payable	'	'	54,621	'	'	'
Accounts payable to related parties	'	'	7,134	'	'	'
Gas imbalances	'	'	3,142	'	'	'
Derivative liabilities at fair value	'	'	184	'	'	'
Accrued taxes	'	'	4,427	'	'	'
Accrued other current liabilities	'	'	14,777	'	'	'
Total Current Liabilities	'	'	84,285	'	'	'
Long-term debt	'	'	135,000	'	'	'
Other long-term liabilities and deferred credits	'	'	4,572	'	'	'
Total Long-term Liabilities	'	'	139,572	'	'	'
Partners' Capital	'	'	743,941	'	'	'
Total Liabilities and Equity	'	'	$967,798	'	'	'

Business_Combinations_Impact_o1

Business Combinations Impact of Acquisition, Income Statement (Details) (USD $)	2 Months Ended	1 Months Ended		3 Months Ended		4 Months Ended	6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Natural gas liquids sales	'	'	'	$36,329	$31,690	'	$85,236	$65,091	'
Natural gas sales	'	'	'	2,713	4,248	'	7,521	4,698	'
Transportation services	'	'	'	30,569	30,909	'	64,673	60,527	'
Processing and other revenues	'	'	'	7,709	2,500	'	14,669	4,719	'
Total Revenues	900	'	'	77,320	69,347	'	172,099	135,035	'
Cost of sales and transportation services	'	'	'	41,172	35,257	'	93,240	66,443	'
Operations and maintenance	'	'	'	10,055	9,229	'	18,068	16,592	'
Depreciation and amortization	'	'	'	8,768	9,332	'	16,320	18,722	'
General and administrative	'	'	'	7,124	6,517	'	13,773	12,544	'
Taxes, other than income taxes	'	'	'	1,639	1,663	'	3,595	3,709	'
Total Operating Costs and Expenses	'	'	'	68,758	61,998	'	144,996	118,010	'
Operating Income	'	'	'	8,562	7,349	'	27,103	17,025	'
Interest (expense) income, net	'	'	'	-2,140	-3,495	'	-3,433	-9,059	'
Loss on extinguishment of debt	'	'	'	0	-17,526	'	0	-17,526	-17,500
Other Nonoperating Income (Expense)	'	'	'	729	445	'	1,669	801	'
Total Other Expense	'	'	'	8,250	-20,576	'	8,341	-25,784	'
Net Income (loss) attributable to partners	-200	-14,949	1,722	16,867	-13,227	6,190	35,499	-8,759	'
Tallgrass Energy Partners [Member]	'	'	'	'	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Natural gas liquids sales	'	'	'	'	31,690	'	'	65,091	'
Natural gas sales	'	'	'	'	3,888	'	'	4,189	'
Transportation services	'	'	'	'	25,324	'	'	49,661	'
Processing and other revenues	'	'	'	'	2,500	'	'	4,719	'
Total Revenues	'	'	'	'	63,402	'	'	123,660	'
Cost of sales and transportation services	'	'	'	'	32,358	'	'	61,828	'
Operations and maintenance	'	'	'	'	8,305	'	'	14,840	'
Depreciation and amortization	'	'	'	'	7,436	'	'	14,982	'
General and administrative	'	'	'	'	5,039	'	'	9,673	'
Taxes, other than income taxes	'	'	'	'	1,394	'	'	3,171	'
Total Operating Costs and Expenses	'	'	'	'	54,532	'	'	104,494	'
Operating Income	'	'	'	'	8,870	'	'	19,166	'
Interest (expense) income, net	'	'	'	'	-3,500	'	'	-9,064	'
Loss on extinguishment of debt	'	'	'	'	-17,526	'	'	-17,526	'
Other Nonoperating Income (Expense)	'	'	'	'	429	'	'	768	'
Total Other Expense	'	'	'	'	-20,597	'	'	-25,822	'
Net Income (loss) attributable to partners	'	'	'	'	-11,727	'	'	-6,656	'
Trailblazer Pipeline Company LLC [Member]	'	'	'	'	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Natural gas liquids sales	'	'	'	'	0	'	'	0	'
Natural gas sales	'	'	'	'	360	'	'	509	'
Transportation services	'	'	'	'	5,585	'	'	10,866	'
Processing and other revenues	'	'	'	'	0	'	'	0	'
Total Revenues	'	'	'	'	5,945	'	'	11,375	'
Cost of sales and transportation services	'	'	'	'	2,899	'	'	4,615	'
Operations and maintenance	'	'	'	'	924	'	'	1,752	'
Depreciation and amortization	'	'	'	'	1,896	'	'	3,740	'
General and administrative	'	'	'	'	1,478	'	'	2,871	'
Taxes, other than income taxes	'	'	'	'	269	'	'	538	'
Total Operating Costs and Expenses	'	'	'	'	7,466	'	'	13,516	'
Operating Income	'	'	'	'	-1,521	'	'	-2,141	'
Interest (expense) income, net	'	'	'	'	5	'	'	5	'
Loss on extinguishment of debt	'	'	'	'	0	'	'	0	'
Other Nonoperating Income (Expense)	'	'	'	'	16	'	'	33	'
Total Other Expense	'	'	'	'	21	'	'	38	'
Net Income (loss) attributable to partners	'	'	'	'	($1,500)	'	'	($2,103)	'

Business_Combinations_BNN_Acqu

Business Combinations BNN Acquisition, Assets Acquired & Liabilities Assumed (Details) (USD $)	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	13-May-14
In Thousands, unless otherwise specified							BNN Water Solutions [Member]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net [Abstract]	'	'	'	'	'	'	'
Accounts receivable	$27,698	'	$30,033	'	'	'	$790
Property, plant and equipment	660,251	'	657,780	'	'	'	4,100
Intangible assets	7,495	'	0	'	'	'	8,200	[1]
Accounts payable and accrued liabilities	'	'	'	'	'	'	-134
Distribution payable	-400	'	'	'	'	'	-634
Net identifiable assets acquired	'	'	'	'	'	'	12,322
Goodwill	343,288	334,715	334,715	333,157	333,157	333,157	8,573
Net assets acquired	'	'	'	'	'	'	$20,895
[1]	The $8.2 million intangible asset acquired represents a major customer contract and is subject to amortization over the remaining contract term (approximately 1.6 years). Amortization of $0.7 million was recorded during the period from May 13, 2014 to June 30, 2014.

Business_Combinations_Pro_Form

Business Combinations Pro Forma Revenue & Net Income (Details) (USD $)	3 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014
Business Combinations [Abstract]	'	'
Revenue	$78,084	$174,540
Net income attributable to TEP	$7,642	$26,541

Business_Combinations_Goodwill

Business Combinations Goodwill Roll Forward (Details) (USD $)	3 Months Ended			6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
Goodwill [Roll Forward]	'		'	'		'
Beginning of period	$334,715		$333,157	$334,715		$333,157
Goodwill acquired	8,573		0	8,573		0
End of period	343,288		333,157	343,288		333,157
Gas Transportation And Storage [Member]	'		'	'		'
Goodwill [Roll Forward]	'		'	'		'
Beginning of period	255,558		255,100	255,558		255,100
Goodwill acquired	0		0	0		0
End of period	255,558		255,100	255,558		255,100
Processing [Member]	'		'	'		'
Goodwill [Roll Forward]	'		'	'		'
Beginning of period	79,157		78,057	79,157		78,057
Goodwill acquired	8,573	[1]	0	8,573	[1]	0
End of period	$87,730		$78,057	$87,730		$78,057
[1]	The $8.6 million of goodwill was recorded in connection with the acquisition of a controlling interest in Water Solutions on May 13, 2014.

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	6 Months Ended	12 Months Ended	6 Months Ended		6 Months Ended	3 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Dec. 31, 2014
		mi	General Partner [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Public Company Expense [Member]	Scenario, Forecast [Member]
				TEP [Member]	Tallgrass Development Lp [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'	'
Expected general administrative expense reimbursement	'	'	'	'	'	'	$20,400,000
Expected public company cost reimbursement	'	'	'	'	'	625,000	'
Gas transmission lines sold	'	430	'	'	'	'	'
Reimbursement of Capital Expenditures from Related Party	67,100,000	'	'	'	'	'	'
Reimbursable expenses related to construction of Gas Facilities	'	'	'	'	39,200,000	'	'
Contributions	'	'	27,488,000	'	'	'	'
Accrued liabilities and other liabilities	400,000	'	'	'	'	'	'
Prepayments and other current assets	$1,788,000	$16,986,000	'	$17,000,000	'	'	'

Related_Party_Transactions_Sch

Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Operation and maintenance [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Expenses related to transactions with affiliated companies	$4,608	[1]	$4,597	[1]	$8,956	[1]	$8,716	[1]
General and administrative [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Expenses related to transactions with affiliated companies	$4,305	[1],[2]	$6,247	[1],[2]	$8,887	[1],[2]	$12,200	[1],[2]
[1]	Charges to TEP include directly charged wages and salaries, other compensation and benefits, and shared services.
[2]	During the three and six months ended JuneB 30, 2014 and 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in allocated amounts for general and administrative costs.

Related_Party_Transactions_Sch1

Related Party Transactions - Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Accounts payable to affiliated companies	$3,963	$7,137
Total payables to affiliated companies	3,963	7,137
Tallgrass Operations, LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable to affiliated companies	3,921	7,106
Rockies Express Pipeline LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable to affiliated companies	$42	$31

Related_Party_Transactions_Sch2

Related Party Transactions - Schedule of Balances of Gas Imbalance with Affiliated Shippers (Detail) (Affiliated Shippers [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Affiliated Shippers [Member]	'	'
Related Party Transaction [Line Items]	'	'
Affiliate gas balance receivables	$0	$137
Affiliate gas balance payables	$803	$122

Inventory_Schedule_of_Componen

Inventory - Schedule of Components of Inventory (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Materials and supplies	$2,187	$2,137
Natural gas liquids	1,210	1,009
Gas in underground storage	4,725	2,403
Total inventory	$8,122	$5,549

Property_Plant_and_Equipment_C

Property Plant and Equipment - Components of Property Plant and Equipment (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation and amortization	($35,571)	($22,264)
Property, plant and equipment	660,251	657,780
Natural gas pipelines [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	419,409	397,287
Processing & Treating [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	237,964	209,329
General and other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	30,606	26,076
Construction work in progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	$7,843	$47,352

Risk_Management_Additional_Inf

Risk Management - Additional Information (Detail) (Commodity [Member])	Jun. 30, 2014
	Bcf
Current Portion of Derivative Notional Amount [Member]	'
Derivative [Line Items]	'
Derivative volumes	0.6
Long term Derivative Notional Amount [Member]	'
Derivative [Line Items]	'
Derivative volumes	0.6

Risk_Management_Schedule_of_Fa

Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) (Commodity Contract [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$439	$184
Significant other observable inputs (Level 2) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$439	$184

Risk_Management_Derivative_Con

Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) (Derivatives not designated as hedging contracts [Member], Energy commodity derivative contracts [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivatives not designated as hedging contracts [Member] | Energy commodity derivative contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of loss recognized in income on derivatives	($106)	$635	($458)	($284)
Location of loss recognized in income on derivatives	'	'	'NaturalB gasB sales	'

Risk_Management_Schedule_of_En

Risk Management - Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification (Detail) (Commodity Contract [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$439	$184
Quoted prices in active markets for identical assets (Level 1) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	0	0
Significant other observable inputs (Level 2) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	439	184
Significant unobservable inputs (Level 3) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$0	$0

Longterm_Debt_Additional_Infor

Long-term Debt - Additional Information (Detail) (USD $)

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

6 Months Ended

Jun. 25, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 25, 2014

Jun. 24, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

17-May-13

16-May-13

Nov. 13, 2012

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Maximum [Member]

Minimum [Member]

Scenario, Forecast [Member]

Predecessor [Member]

Predecessor [Member]

Predecessor [Member]

Barclays Bank [Member]

Barclays Bank [Member]

Barclays Bank [Member]

Barclays Bank [Member]

Maximum [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility maturity date

'

'

'

'

'

'

17-May-18

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

$850,000,000

$850,000,000

$500,000,000

$500,000,000

'

'

'

'

'

'

Increase in Swingline Borrowings

60,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in Letters of Credits Sublimit

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in accordion borrowing

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage Change in Borrowing Rate

0.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated leverage ratio

'

'

'

'

'

'

'

'

'

'

4.75

'

5.25

'

'

'

Consolidated interest coverage ratio

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

Credit facility commitment fee

'

'

'

0.38%

'

'

'

'

'

'

0.50%

0.30%

'

'

'

'

Weighted average interest rate on outstanding borrowings

'

1.95%

'

1.95%

'

'

'

'

'

'

'

'

'

'

'

'

Business combination, long-term debt

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000,000

400,000,000

400,000,000

Loss on extinguishment of debt

'

$0

$17,526,000

$0

$17,526,000

$17,500,000

'

'

'

'

'

'

'

'

'

'

Longterm_Debt_Capacity_under_R

Long-term Debt Capacity under Revolving Credit Facility (Details) (Senior Revolving Credit Facility [Member], USD $)	6 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 25, 2014	Jun. 24, 2014	Dec. 31, 2013
			Barclays Bank [Member]	Barclays Bank [Member]	Barclays Bank [Member]	Barclays Bank [Member]
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity	'	'	$850,000,000	$850,000,000	$500,000,000	$500,000,000
Line of Credit Facility, Amount Outstanding	-281,000,000	-135,000,000	'	'	'	'
Credit Facility Letters Of Credit Issued	0	-654,000	'	'	'	'
Line of Credit Facility, Remaining Borrowing Capacity	$569,000,000	$364,346,000	'	'	'	'

Longterm_Debt_Carrying_Amount_

Long-term Debt - Carrying Amount and Fair Value of TEP's Long-term Debt (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Fair Value	$281,000	$135,000
Carrying Amount	281,000	135,000
Quoted prices in active markets for identical assets (Level 1) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	0	0
Significant other observable inputs (Level 2) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	281,000	135,000
Significant unobservable inputs (Level 3) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	$0	$0

Partnership_Equity_and_Distrib2

Partnership Equity and Distributions - Additional Information (Detail) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

17-May-13

Apr. 30, 2014

Apr. 01, 2014

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2013

Aug. 14, 2014

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Tallgrass Development Lp [Member]

Minimum Quarterly Distribution [Member]

Minimum Quarterly Distribution [Member]

Second Target Distribution [Member]

Third Target Distribution [Member]

First Target Distribution [Member]

Thereafter [Member]

General Partner [Member]

General Partner [Member]

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Trailblazer Pipeline Company LLC [Member]

Subsequent Event [Member]

Tallgrass Development Lp [Member]

Tallgrass Development Lp [Member]

Tallgrass Development Lp [Member]

Limited Partners' Capital Account [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Limited Partner, Unit Distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

48,935,140

Distributions per Limited Partner unit

$0.38

[1]

$0.33

$0.32

$0.30

$0.14

[2]

'

'

'

'

'

'

$0.29

$0.29

'

'

'

'

'

'

'

'

'

'

General partner interest in TEP

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

General partner units issued

834,391

'

826,531

'

'

834,391

'

826,531

7,860

7,860

'

'

'

'

'

'

'

'

'

'

'

'

'

Increasing incentive distribution right

'

'

'

'

'

'

'

'

'

'

'

'

'

13.00%

23.00%

'

48.00%

'

'

'

'

'

'

Incentive distribution per unit

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.35

$0.43

$0.30

'

'

'

'

'

'

'

Percentage of unit holders

'

'

'

'

'

'

'

'

'

'

'

'

'

85.00%

75.00%

98.00%

50.00%

'

'

'

'

'

'

Percentage of general partner

'

'

'

'

'

'

'

'

'

'

'

'

'

15.00%

25.00%

2.00%

50.00%

'

'

'

'

'

'

Excess purchase price over carrying value of acquired interests in Trailblazer

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$72,900,000

$72,933,000

'

'

'

'

Distributions to Predecessor Member, net

'

'

'

'

'

2,893,000

1,215,000

'

'

'

119,753,000

'

'

'

'

'

'

'

'

0

2,900,000

1,200,000

'

Cash paid for contribution of pipelines

'

'

'

'

'

'

85,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from underwriters option to purchase additional shares

'

'

'

'

'

'

$31,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The distribution declared on July 1, 2014 for the second quarter of 2014 is expected to be paid August 14, 2014 subsequent to the date of this Quarterly Report on 48,935,140 common units and subordinated units of record at the close of business on July 30, 2014.

[2]

The distribution declared on JulyB 18, 2013 for the second quarter of 2013 represented a prorated amount of the MQD of $0.2875 per common unit, based upon the number of days between the closing of the IPO on MayB 17, 2013 to JuneB 30, 2013.

Partnership_Equity_and_Distrib3

Partnership Equity and Distributions - Summary of Distributions (Detail) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014		Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013
Distribution Made to Limited Partner [Line Items]	'		'	'	'	'
Date Paid	14-Aug-14		14-May-14	12-Feb-14	13-Nov-13	13-Aug-13
Distributions Limited Partners Common	$18,596	[1]	$13,288	$12,757	$12,049	$5,759
Distributions declared	19,684	[1]	13,688	13,082	12,294	5,877
Distributions per Limited Partner unit	$0.38	[1]	$0.33	$0.32	$0.30	$0.14	[2]
General Partner [Member]	'		'	'	'	'
Distribution Made to Limited Partner [Line Items]	'		'	'	'	'
Distributions General Partner Incentive	758	[1]	126	63	0	0
Distributions declared	$330	[1]	$274	$262	$245	$118
[1]	The distribution declared on July 1, 2014 for the second quarter of 2014 is expected to be paid August 14, 2014 subsequent to the date of this Quarterly Report on 48,935,140 common units and subordinated units of record at the close of business on July 30, 2014.
[2]	The distribution declared on JulyB 18, 2013 for the second quarter of 2013 represented a prorated amount of the MQD of $0.2875 per common unit, based upon the number of days between the closing of the IPO on MayB 17, 2013 to JuneB 30, 2013.

Net_Income_per_Limited_Partner2

Net Income per Limited Partner Unit - Summary of Net Income Per Limited Partner Unit (Detail) (USD $)	2 Months Ended	1 Months Ended		3 Months Ended		4 Months Ended	6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'	'	'	'	'
Net Income (Loss)	'	($14,949)	$1,722	$16,812	($13,227)	$6,190	$35,444	($8,759)
Net loss attributable to noncontrolling interests	'	0	0	55	0	0	55	0
Net Income (loss) attributable to partners	-200	-14,949	1,722	16,867	-13,227	6,190	35,499	-8,759
Predecessor operations interest in net loss (income)	'	1,311	189	0	1,500	792	-5,732	2,103
General partner interest in net (income) loss	'	273	-1,911	-1,096	-1,638	-6,982	-1,477	-6,709
Net income (loss) available to common and subordinated unitholders	'	($13,365)	$0	$15,771	($13,365)	$0	$28,290	($13,365)
Basic net income (loss) per common and subordinated unit (usd per share)	'	($0.33)	'	$0.39	($0.33)	'	$0.70	($0.33)
Diluted net income (loss) per common and subordinated unit (usd per share)	'	($0.33)	'	$0.38	($0.33)	'	$0.68	($0.33)
Basic average number of common and subordinated units outstanding (in shares)	'	40,246	'	40,885	40,246	'	40,694	40,246
Equity Participation Unit equivalent units	'	0	'	1,020	0	'	930	0
Diluted average number of common and subordinated units outstanding (in shares)	'	40,246	'	41,905	40,246	'	41,624	40,246

Equity_Based_Compensation_Addi

Equity Based Compensation - Additional Information (Detail) (USD $)	0 Months Ended	3 Months Ended		6 Months Ended
	Jun. 26, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
LTIP expiration period	'	'	'	13-May-23	'
Share-based compensation expense related to the EPU grants recognized	'	2,500,000	85,000	4,700,000	85,000
Compensation cost related to nonvested EPUs expected to be recognized	'	17,900,000	'	17,900,000	'
Weighted average period in which compensation cost related to nonvested EPUs expected to be recognized	'	'	'	'2 years 5 months	'
Maximum [Member]	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Equity participation units granted	'	10,000,000	'	10,000,000	'
TEP [Member]	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Share-based compensation expense related to the EPU grants recognized	'	1,300,000	'	2,200,000	'
Equity Participation Unit [Member]	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Equity participation units granted	1,490,000	111,000	1,490,000	142,500	1,490,000
Equity Participation Unit [Member] | Maximum [Member]	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Equity participation units granted	1,500,000	'	'	'	'
Equity Participation Unit [Member] | Section 16 Officers [Member]	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Equity participation units granted	177,500	'	'	'	'

Equity_Based_Compensation_Summ

Equity Based Compensation - Summarizes Changes in EPUs Outstanding (Detail) (Equity Participation Unit [Member], USD $)	0 Months Ended	3 Months Ended		6 Months Ended
	Jun. 26, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Equity Participation Unit [Member]	'	'	'	'	'
Shares	'	'	'	'	'
Beginning of period, Shares	'	1,486,750	0	1,474,250	0
Granted, Shares	1,490,000	111,000	1,490,000	142,500	1,490,000
Forfeited, Shares	'	-30,250	0	-49,250	0
End of period, Shares	'	1,567,500	1,490,000	1,567,500	1,490,000
Weighted Average Grant Date Fair Value	'	'	'	'	'
Beginning of period, Weighted Average Grant Date Fair Value	'	$17.67	$0	$17.54	$0
Granted, Weighted Average Grant Date Fair Value	'	$31.63	$17.49	$29.86	$17.49
Forfeited, Weighted Average Grant Date Fair Value	'	($17.62)	$0	($17.57)	$0
End of period, Weighted Average Grant Date Fair Value	'	$18.66	$17.49	$18.66	$17.49

Regulatory_Matters_Regulatory_

Regulatory Matters Regulatory Details (Details) (USD $)	Aug. 06, 2012	Jul. 01, 2013	Dec. 31, 2012	Nov. 12, 2012	Dec. 31, 2013
	Tallgrass Interstate Gas Transmission, LLC (TIGT) [Member]	Trailblazer Pipeline Company LLC [Member]	Trailblazer Pipeline Company LLC [Member]	Trailblazer Pipeline Company LLC [Member]	Trailblazer Pipeline Company LLC [Member]
	mi
Entity Information [Line Items]	'	'	'	'	'
Gas transmission lines owned	432	'	'	'	'
Cost of Service used by FERC	'	$25,700,000	'	'	'
Rate of Return	'	10.94%	'	'	'
Unrecovered Fuel Costs	'	'	$578,000	$6,000,000	$8,400,000

Legal_and_Environmental_Matter1

Legal and Environmental Matters - Additional Information (Detail) (USD $)	1 Months Ended			6 Months Ended	0 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Jun. 13, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jul. 03, 2014	Jun. 13, 2013	Jun. 13, 2013
	Segment			TEP [Member]	Subsequent Event [Member]	NEBRASKA	WYOMING
					Tallgrass Interstate Gas Transmission, LLC (TIGT) [Member]	Segment	Segment
Loss Contingencies [Line Items]	'	'	'	'	'	'	'
Aggregate reserves for all claims	'	$0.60	$0.30	'	'	'	'
Loss Contingency, Damages Sought, Value	'	'	'	'	2	'	'
Segments of Pipeline	2	'	'	'	'	1	1
Budgeted cost of remediation activities related to Goshen county failure	'	'	'	0.8	'	'	'
Environmental accruals	'	$5.20	$5	'	'	'	'

Reporting_Segments_Additional_

Reporting Segments - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2014
	Segment
Segment Reporting [Abstract]	'
Number of reportable segments	2

Reporting_Segments_Summary_of_

Reporting Segments - Summary of TEP's Segment Information of Revenue (Detail) (USD $)	2 Months Ended	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	$900	$77,320	$69,347	$172,099	$135,035
Gas Transportation And Storage [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	32,610	33,635	70,986	62,491
Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	44,710	35,712	101,113	72,544
Corporate and Other [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	0	0	0	0
Operating Segments [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	77,320	69,546	172,099	135,405
Operating Segments [Member] | Gas Transportation And Storage [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	32,610	33,834	70,986	62,861
Operating Segments [Member] | Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	44,710	35,712	101,113	72,544
Operating Segments [Member] | Corporate and Other [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	0	0	0	0
Inter-Segment [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	0	-199	0	-370
Inter-Segment [Member] | Gas Transportation And Storage [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	0	-199	0	-370
Inter-Segment [Member] | Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	0	0	0	0
Inter-Segment [Member] | Corporate and Other [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	'	$0	$0	$0	$0

Reporting_Segments_Summary_of_1

Reporting Segments - Summary of TEP's Segment Information of Earnings (Detail) (USD $)	2 Months Ended	1 Months Ended		3 Months Ended		4 Months Ended	6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013	16-May-13	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Reconciliation to Net Income:	'	'	'	'	'	'	'	'	'
Interest expense (income), net	'	'	'	$2,140	$3,495	'	$3,433	$9,059	'
Depreciation and amortization expense	'	'	'	8,768	9,332	'	16,320	18,722	'
Loss on extinguishment of debt	'	'	'	0	17,526	'	0	17,526	17,500
Non-cash compensation expense	'	'	'	'	'	'	2,249	85	'
Equity in earnings of unconsolidated investment	'	'	'	-273	0	'	-717	0	'
Gain on remeasurement of unconsolidated investment	'	'	'	-9,388	0	'	-9,388	0	'
Net Income (loss) attributable to partners	-200	-14,949	1,722	16,867	-13,227	6,190	35,499	-8,759	'
Gas Transportation And Storage [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	15,066	11,235	'	34,928	24,571	'
Processing [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	5,511	5,435	'	15,107	12,440	'
Corporate and Other [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	-625	-307	'	-1,250	-307	'
Operating Segments [Member] | Gas Transportation And Storage [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	15,066	11,434	'	34,928	24,941	'
Operating Segments [Member] | Processing [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	5,511	5,236	'	15,107	12,070	'
Operating Segments [Member] | Corporate and Other [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	-625	-307	'	-1,250	-307	'
Inter-Segment [Member] | Gas Transportation And Storage [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	0	-199	'	0	-370	'
Inter-Segment [Member] | Processing [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	0	199	'	0	370	'
Inter-Segment [Member] | Corporate and Other [Member]	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Adjusted EBITDA	'	'	'	0	0	'	0	0	'
Segment Reconciling Items [Member]	'	'	'	'	'	'	'	'	'
Reconciliation to Net Income:	'	'	'	'	'	'	'	'	'
Interest expense (income), net	'	'	'	2,140	3,495	'	3,433	9,059	'
Depreciation and amortization expense	'	'	'	8,622	9,332	'	16,174	18,722	'
Loss on extinguishment of debt	'	'	'	0	17,526	'	0	17,526	'
Non-cash gain related to derivative instruments	'	'	'	-96	-848	'	255	71	'
Non-cash compensation expense	'	'	'	1,308	85	'	2,249	85	'
Distributions from unconsolidated investment	'	'	'	772	0	'	1,280	0	'
Equity in earnings of unconsolidated investment	'	'	'	-273	0	'	-717	0	'
Gain on remeasurement of unconsolidated investment	'	'	'	'	'	'	-9,388	0	'
Net Income (loss) attributable to partners	'	'	'	$16,867	($13,227)	'	$35,499	($8,759)	'

Reporting_Segments_Summary_of_2

Reporting Segments - Summary of TEP's Segment Information of Assets (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Segment Reporting Information [Line Items]	'	'
Segment assets	$1,067,315	$1,065,257
Gas Transportation And Storage [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	717,695	734,145
Processing [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	344,064	326,599
Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	$5,556	$4,513

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	0 Months Ended				0 Months Ended		6 Months Ended	0 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 25, 2014	Jul. 25, 2014	Jul. 21, 2014	Jun. 30, 2014	Jul. 21, 2014	Jul. 21, 2014	Jun. 30, 2014	Jul. 25, 2014
	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Ownership Interests Held By Public [Member]	Ownership Interests Held By Public [Member]
				mi	Subsequent Event [Member]	Subsequent Event [Member]		Subsequent Event [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'
Percentage of Voting Interests Offered	'	'	33.30%	'	'	33.30%	'	'
Total Consideration	'	'	'	'	$600	'	'	'
Miles Of Gas Pipeline Converted To Oil	'	'	'	430	'	'	'	'
Miles of Pipeline Constructed	'	'	'	260	'	'	'	'
Miles of Lateral Constructed	'	'	'	66	'	'	'	'
Initial public offering of common units	'	'	'	'	'	'	14,600,000	8,050,000
Shares Issued, Price Per Share	'	$41.07	'	'	'	'	'	'
Shares Issued, Price Per Share, Net of Underwriters Discount	'	$39.74	'	'	'	'	'	'
Partners' Capital Account, Public Sale of Units	$319.50	'	'	'	'	'	'	'