Tallgrass Energy Partners 10-Q 7 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013	Nov. 01, 2013	Nov. 01, 2013
		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-Sep-13	'	'	'
Document Fiscal Year Focus	'2013	'	'	'
Document Fiscal Period Focus	'Q3	'	'	'
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	'	24,300,000	16,200,000	826,531

CONDENSED_COMBINED_STATEMENTS_

CONDENSED COMBINED STATEMENTS OF INCOME (USD $)	3 Months Ended	9 Months Ended			3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012
			TD [Member]	Beginning of the period to May 16, 2013 [Member]	May 17, 2013 to September 30, 2013 [Member]	May 17, 2013 to September 30, 2013 [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]
Revenues:	'	'	'	'	'	'	'	'
Natural gas liquids sales	$32,216	$97,307	'	'	'	'	$28,519	$91,257
Natural gas sales	3,053	7,242	'	'	'	'	7,705	13,118
Transportation services	23,785	73,446	'	'	'	'	26,801	81,565
Other operating revenues	4,205	8,924	'	'	'	'	1,453	4,586
Total Revenues	63,259	186,919	'	'	'	'	64,478	190,526
Operating Costs and Expenses:	'	'	'	'	'	'	'	'
Cost of sales and transportation services (exclusive of depreciation and amortization shown below)	31,465	91,850	'	'	'	'	31,060	85,393
Operations and maintenance	9,430	25,713	'	'	'	'	10,146	28,154
Depreciation and amortization	7,342	22,324	'	'	'	'	5,949	17,776
General and administrative	6,071	15,744	'	'	'	'	2,894	9,593
Taxes, other than income taxes	1,577	4,748	'	'	'	'	2,077	6,153
Total Operating Costs and Expenses	55,885	160,379	'	'	'	'	52,126	147,069
Operating Income	7,374	26,540	'	'	'	'	12,352	43,457
Other Income (Expense):	'	'	'	'	'	'	'	'
Interest (expense) income, net	-1,422	-1,458	-9,028	'	'	'	1,446	1,446
Loss on extinguishment of debt	'	-17,526	'	'	'	'	'	'
Other income (expense), net	1,054	1,822	'	'	'	'	87	-94
Total Other (Expense) Income	-368	-26,190	'	'	'	'	1,533	1,352
Income Before Income Taxes	7,006	350	'	'	'	'	13,885	44,809
Texas Margin Taxes	'	'	'	'	'	'	20	193
Net Income	7,006	350	'	6,982	7,006	-6,632	13,865	44,616
Allocation of income for the three and nine months ended September 30, 2013:	'	'	'	'	'	'	'	'
Net Income (Loss)	7,006	350	'	6,982	7,006	-6,632	13,865	44,616
General partner interest in net income (loss) for the period from May 17, 2013 to September 30, 2013	140	6,849	'	'	140	-133	'	'
Basic net income (loss) per common and subordinated unit	$0.17	($0.16)	'	'	'	'	'	'
Common and subordinated unitholders' interest in net income (loss) for the period from May 17, 2013 to September 30, 2013	$6,866	($6,499)	'	'	$6,866	($6,499)	'	'
Diluted net income (loss) per common and subordinated unit	$0.17	($0.16)	'	'	'	'	'	'
Basic average number of common and subordinated units outstanding	40,500	40,417	'	'	'	'	'	'
Diluted average number of common and subordinated units outstanding	40,863	40,417	'	'	'	'	'	'

CONDENSED_COMBINED_STATEMENTS_1

CONDENSED COMBINED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012
			TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]
Net Income	$7,006	$350	$13,865	$44,616
Other Comprehensive Income:	'	'	'	'
Reclassification of change in fair value of derivatives to net income	'	'	-1,584	-3,535
Change in fair value of derivatives utilized for hedging purposes	'	'	-366	978
Total Other Comprehensive Loss	'	'	-1,950	-2,557
Comprehensive Income	$7,006	$350	$11,915	$42,059

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$620	'
Accounts receivable, net	22,238	17,848
Accounts receivable from related parties	1,672	6,463
Gas imbalances	1,496	1,282
Inventories	2,670	2,204
Derivative assets at fair value	24	224
Prepayments and other current assets	377	47
Total Current Assets	29,097	28,068
Property, plant and equipment, net	671,720	669,476
Goodwill	302,916	301,852
Deferred financing costs	4,774	'
Other deferred charges	17,729	23,066
Total Assets	1,026,236	1,035,814
Current Liabilities:	'	'
Accounts payable	33,602	35,496
Accounts payable to related parties	1,353	'
Notes payable to related parties	'	1,387
Gas imbalances	2,287	1,250
Derivative liabilities at fair value	5	23
Accrued taxes	4,796	3,465
Current portion of long-term debt allocated from TD	'	4,000
Accrued other current liabilities	13,633	26,233
Total Current Liabilities	55,676	71,854
Long-term debt	226,000	390,491
Other long-term liabilities and deferred credits	4,215	1,635
Total Long-term Liabilities	230,215	392,126
Commitments and Contingencies (Note 15)	'	'
Partners' Capital:	'	'
General partner (826,531 units issued and outstanding at September 30, 2013)	13,984	'
Member's Capital	'	571,834
Total Partners' Capital	740,345	571,834
Total Liabilities and Partners' Capital	1,026,236	1,035,814
TD [Member]	'	'
Current Assets:	'	'
Deferred financing costs	'	13,352
Current Liabilities:	'	'
Current portion of long-term debt allocated from TD	'	4,000
Long-term debt	'	390,491
Common unitholders [Member]	'	'
Partners' Capital:	'	'
Partner's capital	452,273	'
Subordinated unitholder [Member]	'	'
Partners' Capital:	'	'
Partner's capital	$274,088	'

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical)	Sep. 30, 2013
General partner units issued	826,531
General partner units outstanding	826,531
Common unitholders [Member]	'
Partner's capital units issued	24,300,000
Partner's capital units outstanding	24,300,000
Subordinated unitholder [Member]	'
Partner's capital units issued	16,200,000
Partner's capital units outstanding	16,200,000

CONDENSED_COMBINED_STATEMENT_O

CONDENSED COMBINED STATEMENT OF CASH FLOWS (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
		TEP Pre-Predecessor [Member]
Cash Flows from Operating Activities:	'	'
Net Income	$350	$44,616
Adjustments to reconcile net income to net cash flows from operating activities:	'	'
Depreciation and amortization	23,802	17,776
Loss on extinguishment of debt	17,526	'
Noncash compensation expense	948	'
Changes in components of working capital:	'	'
Accounts receivable and other	8,614	4,843
Gas imbalances	823	3,821
Inventories	-185	-91
Accounts payable and accrued liabilities	-630	-4,476
Regulatory assets	-111	'
Other, net	-209	618
Net Cash Provided by Operating Activities	50,928	67,107
Cash Flows from Investing Activities:	'	'
Capital expenditures	-37,718	-12,566
Net cash paid for purchase and sale of gas in underground storage	'	-1,147
Disposal of property, plant and equipment (net of removal costs)	-274	145
Net Cash Used in Investing Activities	-37,992	-13,568
Cash Flows from Financing Activities:	'	'
Repayment of debt assumed from TD	-400,000	'
Borrowings under revolving credit facility, net	226,000	'
Payments for deferred financing costs	-5,157	'
Proceeds from initial public offering, net of offering costs	290,498	'
Distributions to Member, net	-118,538	-53,539
Distributions to unitholders	-5,877	'
Reimbursement of stock compensation expense from TD	758	'
Net Cash Used in Financing Activities	-12,316	-53,539
Net Change in Cash and Cash Equivalents	620	'
Cash and Cash Equivalents, beginning of period	'	'
Cash and Cash Equivalents, end of period	620	'
Supplemental Disclosures:	'	'
Cash payments for interest	2,155	'
Schedule of Noncash Investing and Financing Activities:	'	'
Fair value of TIGT and TMID assets contributed by TD	1,027,127	'
Fair value of TIGT and TMID liabilities contributed by TD	-566,849	'
Increase in accrual for reimbursable construction in progress projects	3,516	'
Receivable for unreimbursed stock compensation from TD	$373	'

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL (USD $)

Total

TD [Member]

TEP Predecessor Member's Capital [Member]

TEP Predecessor Member's Capital [Member]

Beginning of the period to May 16, 2013 [Member]

Beginning of the period to May 16, 2013 [Member]

May 17, 2013 to September 30, 2013 [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

General Partner [Member]

General Partner [Member]

In Thousands

TD [Member]

TEP Predecessor Member's Capital [Member]

Common unitholders [Member]

Subordinated unitholder [Member]

May 17, 2013 to September 30, 2013 [Member]

May 17, 2013 to September 30, 2013 [Member]

May 17, 2013 to September 30, 2013 [Member]

Common unitholders [Member]

Subordinated unitholder [Member]

Balance at beginning of period at Dec. 31, 2012

$571,834

'

$571,834

'

'

'

'

'

'

'

'

'

'

Net Income (Loss)

350

'

'

'

6,982

6,982

-6,632

'

'

-3,899

-2,600

'

-133

Contribution of net assets of TIGT and TMID

'

'

-460,278

'

'

'

'

167,051

278,992

'

'

14,235

'

Issuance of units to public (including underwriter over-allotment), net of offering and other costs

290,498

'

'

'

'

'

'

290,498

'

'

'

'

'

Distributions

-5,877

-118,538

'

-118,538

'

'

'

-3,455

-2,304

'

'

-118

'

Noncash compensation expense

948

'

'

'

'

'

'

2,078

'

'

'

'

'

Ending Balance at Sep. 30, 2013

$740,345

'

'

'

'

'

'

$452,273

$274,088

'

'

$13,984

'

Description_of_Business

Description of Business	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Description of Business	'
	1	Description of Business
	Tallgrass Energy Partners, LP (“TEP”) is a Delaware limited partnership formed in February 2013. On May 17, 2013, TEP closed its initial public offering (the “Offering”) of 14,600,000 common units at a price of $21.50 per unit, which included 1,550,000 of a possible 1,957,500 common units from the partial exercise of the over-allotment option by the underwriters. Proceeds to TEP from the sale of the common units were approximately $295.9 million, net of the underwriters’ discount. In addition, TEP recognized $5.4 million of other costs associated with the offering, including legal, accounting, printing and consulting fees, resulting in total net proceeds of $290.5 million.
	In connection with the Offering, Tallgrass Development, LP (“TD”) contributed 100% of the membership interests in TIGT and TMID, as each is defined below, to TEP in exchange for (i) 9,700,000 common units, inclusive of the remaining 407,500 overallotment units not issued to the underwriters, and 16,200,000 subordinated units, (ii) TEP’s assumption of $400 million of indebtedness related to TD’s acquisition of TIGT and TMID and (iii) $85.5 million in cash as reimbursement for a portion of the capital expenditures made by TD to purchase the contributed assets. In addition, a payment of approximately $31.2 million, equal to the net proceeds from the issuance of the overallotment units to the underwriters, was distributed by TEP to TD. At the closing of the Offering, TEP used the total proceeds, net of the underwriters’ discount, of approximately $295.9 million to repay approximately $295.9 million of the debt assumed from TD.
	The 14,600,000 common units held by the public constitute approximately 36% of TEP’s outstanding limited partner interests and approximately 35% of TEP’s total equity, exclusive of Incentive Distribution Rights (“IDRs”). TD’s 9,700,000 common units and 16,200,000 subordinated units collectively comprise approximately 64% of TEP’s outstanding limited partner interests and approximately 63% of TEP’s overall equity, exclusive of IDRs. In addition, as part of the contribution transaction, 826,531 general partner units, representing a 2% general partner interest in TEP, and all of our IDRs were issued to Tallgrass MLP GP, LLC (the “GP”). For detail regarding the IDRs see Note 10 – Partnership Equity and Distributions. In connection with the Offering, TEP entered into a revised partnership agreement on May 17, 2013. The revised partnership agreement requires TEP to distribute its available cash on a quarterly basis, subject to certain terms and conditions, beginning with the quarter ended June 30, 2013. For additional information, see Note 10 – Partnership Equity and Distributions.
	The term “Predecessor Entities” refers to both Tallgrass Energy Partners Predecessor (“TEP Predecessor”) and Tallgrass Energy Partners Pre-Predecessor (“TEP Pre-Predecessor”), which are comprised of the businesses described below that were owned by Kinder Morgan Energy Partners, LP (“TEP Pre-Predecessor Parent”) prior to November 13, 2012. On November 13, 2012, TEP Pre-Predecessor Parent sold those assets, among others, to TD. The Predecessor Entities are referred to as TEP Predecessor for the period in which they were owned by TD, from November 13, 2012 through the completion of the Offering on May 17, 2013, and as TEP Pre-Predecessor for periods in which they were owned by TEP Pre-Predecessor Parent, prior to November 13, 2012.
	The businesses included in the Predecessor Entities consist of:
		•	Tallgrass Interstate Gas Transmission, LLC (“TIGT”), an interstate gas pipeline and storage system that is regulated by the Federal Energy Regulatory Commission (“FERC”). TIGT currently has approximately 5,250 miles of varying diameter natural gas transmission lines in Colorado, Kansas, Missouri, Nebraska and Wyoming. Upon receipt of FERC approval and completion of construction of certain gas facilities necessary to maintain existing natural gas service, TIGT will sell approximately 432 miles of natural gas pipeline, along with the associated rights of way and certain other equipment, to a subsidiary of TD. For more information, see Note 14 – Regulatory Matters.
		•	Tallgrass Midstream, LLC (“TMID”) is a Delaware limited liability company that owns and operates one treating and two processing plants in Wyoming.
	Prior to the sale of these assets to TD on November 13, 2012, TIGT was named Kinder Morgan Interstate Gas Transmission LLC and TMID was named KM Upstream LLC.
	For additional information regarding the acquisition of TIGT and TMID, see Note 3 – Business Combinations.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	2	Summary of Significant Accounting Policies
	Basis of Presentation
	These unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2013 and the unaudited condensed combined financial statements for the three and nine months ended September 30, 2012 have been prepared in accordance with 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 nine months ended September 30, 2013 and the unaudited condensed combined financial statements for the three and nine months ended September 30, 2012 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.
	Our financial results for the three and nine months ended September 30, 2013 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2013. These unaudited condensed consolidated financial statements should be read in conjunction with our combined financial statements and notes thereto included in our final prospectus dated May 13, 2013 (the “Prospectus”) and filed with the Securities Exchange Commission (the “SEC”) pursuant to Rule 424 on May 14, 2013.
	The accompanying unaudited condensed consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to us by TD in connection with the Offering for the periods prior to May 17, 2013, the closing date of TEP’s Offering, 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 transfer 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.
	The condensed combined financial statements of the Predecessor Entities include legal entities, as detailed above, that are indirect wholly-owned subsidiaries of the Predecessor Entities. As the condensed combined financial statements reflect TEP Predecessor and TEP Pre-Predecessor as single entities, significant intra-entity items have been eliminated in the presentation. Net equity distributions of the Predecessor Entities included in the Condensed Combined Statements of Equity and Condensed Combined Statements of Cash Flows represent transfers of cash as a result of TD and TEP Pre-Predecessor Parent’s centralized cash management systems prior to May 17, 2013, 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.
	TEP’s financial results as presented on the condensed consolidated statements of income, comprehensive income and cash flows have been separated from TEP Pre-Predecessor’s financial results by a bold vertical black line.
	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 or the Predecessor Entities’ 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.
	New Accounting Pronouncements Adopted
	ASU No. 2011-11, Balance Sheet (Topic 210), “Disclosures about Offsetting Assets and Liabilities” and ASU No. 2013-01, Balance Sheet (Topic 210), “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities”
	On December 16, 2011, the FASB issued ASU No. 2011-11, Balance Sheet (Topic 210), “Disclosures about Offsetting Assets and Liabilities”. ASU 2011-11 requires entities to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. In January 2013, the FASB issued ASU No. 2013-01, Balance Sheet (Topic 210), “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities,” which clarifies that the scope of ASU No. 2011-11 applies to derivatives accounted for in accordance with the Codification guidance for derivatives and hedging transactions, including bifurcated embedded derivatives, repurchase agreements and reverse purchase agreements, and certain securities borrowing and securities lending transactions. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The adoption of ASU 2011-11 on January 1, 2013 did not have a material impact on TEP’s financial statements.
	ASU No. 2013-02, Comprehensive Income (Topic 220), “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”
	In February 2013, the FASB issued ASU No. 2013-02, Comprehensive Income (Topic 220), “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”. ASU 2013-02 does not change the current requirements for reporting net income or other comprehensive income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component, either on the face of the statement where net income is presented or in the notes, depending on whether or not the amount reclassified is required under GAAP to be reclassified to net income in its entirety in the same reporting period. ASU 2013-02 is effective for public entities prospectively for reporting periods beginning after December 15, 2012, or January 1, 2013 for TEP. The adoption of ASU 2013-02 did not have a material impact on TEP’s financial statements.

Business_Combinations

Business Combinations	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
Business Combinations	'
	3	Business Combinations
	On November 13, 2012, TD completed the acquisition of certain assets from TEP Pre-Predecessor Parent for approximately $1.8 billion in cash and approximately $1.5 billion of assumed debt. The acquisition included a 100% equity interest in both TIGT and TMID, as discussed in Note 1 – Description of Business. Of the approximately $1.8 billion in cash paid to acquire all of the net assets, $573.2 million was allocated to TIGT and TMID. The contribution of the assets and liabilities of TIGT and TMID from TD to TEP, which was effective on May 17, 2013, was accounted for as a transaction between entities under common control under ASC 805.
	At December 31, 2012, the assets acquired and liabilities assumed in the acquisition were recorded at provisional amounts based on the preliminary purchase price allocation. TD 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 retrospectively adjusted 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.
	During the nine months ended September 30, 2013, the preliminary purchase price allocation was adjusted for certain immaterial items related to regulatory assets and accrued liabilities. As the changes were not considered material to TEP or the purchase price allocation, the adjustments are not retrospectively reflected in the accompanying condensed combined balance sheet as of December 31, 2012.
	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 concurrently with the Offering, and was therefore allocated to TIGT and TMID along with the related deferred financing costs at November 13, 2012. On May 17, 2013, concurrently with the closing of the Offering, this $400 million of the long-term debt held by TD was assumed and repaid by TEP. TIGT and TMID were also released as guarantors of the TD debt and became guarantors of the TEP revolving credit facility. For additional information, see Note 9 – Long-term Debt.
	The goodwill recorded in the condensed consolidated balance sheet is expected to be deductible for tax purposes. The goodwill is primarily attributable to (i) the strategic location of the assets, including access to key supply sources and major customer demand markets; (ii) the complementary location of the assets relative to each other and relative to key market areas; (iii) growth opportunities through production growth requiring processing in the Rockies; (iv) future pipeline interconnects and fertilizer and power plant conversions that may potentially provide volume growth opportunities; and (v) a trained workforce. For additional information regarding goodwill, see Note 7 – Goodwill.
	The following unaudited pro forma financial information for the historical periods is presented as if the acquisition of TIGT and TMID had been completed on January 1, 2012. 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 Pre-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.
			TEP Pre-Predecessor
			Three Months		Nine Months
			Ended		Ended
			September 30, 2012		September 30, 2012
			(in thousands)
	Revenue		$	64,478	$	190,526
	Net income		$	6,497	$	22,512
	Pro forma revenue contains no adjustments to the historical amounts. Pro forma net income includes adjustments for the three and nine months ended September 30, 2012 to give effect to the following:
		(a)	Reduction in net income to reflect additional depreciation expense associated with the increase in the cost of property, plant and equipment that resulted from the allocation of the purchase price to the fair value of the assets and liabilities acquired by TD.
		(b)	Reduction in net income to reflect interest expense on the long-term debt allocated to TIGT and TMID in connection with the acquisition of TIGT and TMID by TD.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	4	Related Party Transactions
	TEP has no employees. TEP Pre-Predecessor Parent historically provided and charged TEP Pre-Predecessor 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. Beginning November 13, 2012, TD provided and charged TEP for similar direct and indirect costs of services. TEP and TEP Pre-Predecessor record these costs on the accrual basis in the period in which TEP Pre-Predecessor Parent (or TD, beginning November 13, 2012) incurs them. Each of the wholly-owned companies comprising TEP and TEP Pre-Predecessor had agency arrangements with TEP Pre-Predecessor Parent or its affiliates (prior to November 13, 2012) and TD (beginning November 13, 2012) under which TEP Pre-Predecessor Parent, or its contractually obligated affiliate, or TD, as applicable, pay costs and expenses incurred by TEP and TEP Pre-Predecessor, act as agents for TEP and TEP Pre-Predecessor, and are reimbursed by TEP and TEP Pre-Predecessor for such payments. While the substance of the operating agreement remains the same, the cost structure under new management has changed, which affected the basis of certain allocations when the agreements transitioned from TEP Pre-Predecessor Parent to TD.
	On May 17, 2013, in connection with the closing of the Offering, TEP and its subsidiaries entered into an Omnibus Agreement with TD and certain of its affiliates. 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 our 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 2013, TEP’s annual cost reimbursements to TD for costs discussed above, are expected to be $18.5 million. Effective May 17, 2013, TEP will also pay a quarterly reimbursement to TD for costs associated with being a public company. The quarterly public company reimbursement amount is expected to be $625,000 in 2013. 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 agreements discussed in Note 2 – Summary of Significant Accounting Policies, intercompany balances between the Predecessor Entities were periodically settled and treated as equity distributions prior to the completion of the Offering on May 17, 2013.
	Totals of transactions with affiliated companies are as follows:
			TEP					TEP Pre-Predecessor		TEP			TEP Pre-Predecessor
			Three Months					Three Months		Nine Months			Nine Months
			Ended					Ended		Ended			Ended
			September 30,					September 30,		September 30,			September 30,
			2013					2012		2013			2012
			(in thousands)					(in thousands)		(in thousands)			(in thousands)
	Cost of sales and transportation services		$	1,119				$	680	$	1,016		$	4,313
	Charges to TEP and TEP Pre-Predecessor: (1)
	Property, plant and equipment, net		$	140				$	153	$	4,979		$	990
	Other deferred charges		$	6				$	49	$	1,098		$	106
	Operation and maintenance		$	3,863				$	3,721	$	11,461		$	11,575
	General and administrative		$	6,006	(2)			$	3,038	$	15,594	(2)	$	7,740
	(1)	Charges to TEP and TEP Pre-Predecessor include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three and nine months ended September 30, 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in a single allocated amount for general and administrative costs rather than individual charges as in prior periods.
	Details of balances with affiliates included in “Accounts receivable” and “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
			September 30, 2013			December 31, 2012
			(in thousands)
	Accounts receivable from affiliated companies:
	Tallgrass Operations, LLC		$	—		$	6,244
	Rockies Express Pipeline LLC			1,672			219
	Total accounts receivable from affiliated companies		$	1,672		$	6,463
	Payables to affiliated companies:
	Note payable to TD		$	—		$	1,381
	Interest payable to TD			—			6
	Accounts payable to Tallgrass Operations, LLC			1,307			—
	Accounts payable to Rockies Express Pipeline LLC			46			—
	Total payables to affiliated companies		$	1,353		$	1,387
	As of September 30, 2013 and December 31, 2012, TEP had $0.9 million and $0.3 million, respectively, in gas imbalance payables with affiliated entities.
	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, LLC (“PXP”) is reimbursing TIGT for all costs TIGT incurs with respect to the Pony Express Pipeline Conversation Project, as defined in Note 14 – Regulatory Matters, inclusive of development costs, capital costs and related interest costs associated with securing regulatory approvals for the construction of certain gas facilities necessary to maintain existing natural gas service on the TIGT System (“Replacement Gas Facilities”). The Replacement Gas Facilities are required as part of the Pony Express Pipeline Conversion Project and are being made for TIGT to be able to continue existing service to customers after the Pony Express assets are sold to TD. Expenditures are being captured in Other Deferred Charges on the balance sheet as they are incurred and interest will be accrued until reimbursement takes place. At September 30, 2013 TEP had $6.8 million in Other Deferred Charges related to this project. During the three and nine months ended September 30, 2013, reimbursements of $4.3 million related to expenditures prior to the closing of the Offering on May 17, 2013 were settled as equity distributions with TD. During the three and nine months ended September 30, 2013, reimbursements of $7.7 million related to expenditures subsequent to the closing of the Offering on May 17, 2013 were cash settled with TD.

Inventory

Inventory	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Inventory	'
	5	Inventory
	The components of inventory at September 30, 2013 and December 31, 2012 consisted of the following:
			September 30, 2013		December 31, 2012
			(in thousands)
	Materials and supplies		$	1,606	$	1,567
	Natural gas liquids			770		637
	Gas in underground storage			294		—
	Total inventory		$	2,670	$	2,204

Property_Plant_and_Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2013
Property Plant And Equipment [Abstract]	'
Property, Plant and Equipment	'
	6	Property, Plant and Equipment
	The components of property, plant and equipment at September 30, 2013 and December 31, 2012 consisted of the following:
			September 30, 2013			December 31, 2012
			(in thousands)
	Natural gas pipelines		$	421,756		$	421,644
	Processing and treating assets			199,743			195,108
	Buildings			15,518			15,518
	Vehicles			3,239			3,138
	Gas in underground storage			1,768			2,345
	Land			1,534			1,534
	General and other			1,218			1,207
	Construction work in progress			52,106			32,932
	Accumulated depreciation and amortization			(25,162	)		(3,950	)
	Total property, plant and equipment, net		$	671,720		$	669,476

Goodwill

Goodwill	9 Months Ended
	Sep. 30, 2013
Goodwill And Intangible Assets Disclosure [Abstract]	'
Goodwill	'
	7	Goodwill
	As discussed in Note 3 – Business Combinations, we recorded $302.9 million of goodwill in connection with the acquisition of TIGT and TMID in 2012. Of the $302.9 million of goodwill at September 30, 2013, $224.9 million was assigned to the Gas Transportation and Storage segment and $78.0 million was assigned to the Processing segment. For more information regarding our segments, see Note 12 – Reporting Segments.
	TEP evaluates goodwill for impairment on an annual basis and whenever events or changes in circumstances necessitate an evaluation for impairment. Examples of such facts and circumstances include the excess of fair value over carrying amount in the last valuation or changes in business environment. TEP’s annual impairment testing date is August 31st. TEP evaluates goodwill impairment by reporting unit level, which is an operating segment as defined in the segment reporting guidance of the Codification, using either the qualitative assessment option or the two-step test approach depending on facts and circumstances of the reporting unit. Our reporting units are the same as our reporting segments. If TEP, after performing the qualitative assessment, determines it is “more likely than not” that the fair value of a reporting unit is greater than its carrying amount, the two-step impairment test is unnecessary. When goodwill is evaluated for impairment using the two-step test, the carrying amount of the reporting unit is compared to its fair value in Step 1 and if the fair value exceeds the carrying amount, Step 2 is unnecessary. If the carrying amount exceeds the reporting unit’s fair value, this could indicate potential impairment and Step 2 of the goodwill evaluation process is required to determine if goodwill is impaired and to measure the amount of impairment loss to recognize, if any. When a Step 2 is necessary, the fair value of individual assets and liabilities is determined using valuations, or other observable sources of fair value, as appropriate. If the carrying amount of goodwill exceeds its implied fair value, the excess is recognized as an impairment loss.
	TEP did not elect to apply the qualitative assessment option during our 2013 annual goodwill impairment testing, instead we proceeded directly to the two-step quantitative test. In Step 1 of the two-step quantitative test, we compared the fair value of each reporting unit with its respective book value, including goodwill, by using an income approach based on a discounted cash flow analysis. For the purposes of goodwill impairment testing, goodwill was allocated to our reporting units based on the enterprise value of each reporting unit at the date of acquisition. The fair value of each reporting unit was determined on a stand-alone basis from the perspective of a market participant and included a sensitivity analysis of the impact of changes in various assumptions. This approach required us to make long-term forecasts of future operating results and various other assumptions and estimates, the most significant of which are gross margin, operating expenses, general and administrative expenses, long-term growth rates and the weighted average cost of capital. The fair value of the reporting units was determined using significant unobservable inputs, considered Level 3 under the fair value hierarchy in the Codification. For each reporting unit, the results of the Step 1 impairment analysis indicated no potential impairment as the fair value of the reporting units was substantially greater than their respective book values. As a result, in accordance with the Codification guidance, Step 2 of the impairment analysis was not necessary as part of the annual impairment analysis in 2013. Unpredictable events or deteriorating market or operating conditions could result in a future change to the discounted cash flow models and cause impairments in the future. We continue to monitor potential impairment indicators to determine if a triggering event occurs and will perform additional goodwill impairment analyses as necessary.

Risk_Management

Risk Management

9 Months Ended

Sep. 30, 2013

Derivative Instruments And Hedging Activities Disclosure [Abstract]

'

Risk Management

'

8

Risk Management

TEP and TEP Pre-Predecessor enter into derivative contracts with third parties for the purpose of hedging exposures that accompany their normal business activities. TEP and TEP Pre-Predecessor’s normal business activities expose them to risks associated with changes in the market price of natural gas, among other commodities. 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. Prior to November 13, 2012, TEP Pre-Predecessor applied hedge accounting to these derivative contracts. As discussed below, TEP elected not to apply hedge accounting.

Beginning on November 13, 2012, all previously hedge-designated derivative contracts were de-designated and changes in the fair value of all derivative contracts are now recorded in earnings in the period in which the change occurs. Accumulated other comprehensive income associated with the derivative contracts was immaterial as of the de-designation date and was eliminated in purchase accounting.

During the three and nine months ended September 30, 2012, TEP Pre-Predecessor recognized no gain or loss on derivatives associated with the ineffectiveness of these hedges and did not exclude any component of the derivative contracts’ gain or loss from the assessment of hedge effectiveness. Under hedge accounting, as the hedged sales and purchases took place and TEP Pre-Predecessor recorded them into earnings in the same period, TEP Pre-Predecessor also reclassified the associated gains and losses included in accumulated other comprehensive income into earnings. During the three and nine months ended September 30, 2012, no gain or loss was reclassified into earnings as a result of the discontinuance of cash flow hedges due to a determination that the forecasted transactions would no longer occur by the end of the originally specified time period.

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

September 30, 2013

December 31, 2012

Location

(in thousands)

Energy commodity derivative contracts

Current assets

$

24

$

224

Total derivative assets

$

24

$

224

Balance Sheet

September 30, 2013

December 31, 2012

Location

(in thousands)

Energy commodity derivative contracts

Current liabilities

$

5

$

23

Total derivative liabilities

$

5

$

23

As of September 30, 2013, the fair value shown for commodity contracts was comprised of derivative volumes totaling 0.2 Bcf of both fixed price and basis swaps.

Effect of Derivative Contracts on the Income Statement

The following tables summarize the impact of derivative contracts for the three and nine months ended September 30, 2013 and 2012:

Amount of gain/(loss) recognized in OCI on derivatives (effective portion)

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

September 30, 2012

September 30, 2013

September 30, 2012

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives in cash flow hedging relationships:

Energy commodity derivative contracts

$

—

$

(366

)

$

—

$

978

Amount of (gain)/loss reclassified from Accumulated OCI into  income (effective portion)

Location of gain/

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

(loss) reclassified

from AOCI

into income

(effective portion)

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

30-Sep-12

30-Sep-13

30-Sep-12

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives in cash flow hedging relationships:

Energy commodity derivative contracts

Natural gas sales

$

—

$

1,584

$

—

$

3,535

Amount of gain/(loss) recognized in income on derivatives

Location of gain/

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

(loss) recognized

in income on

derivative

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

30-Sep-12

30-Sep-13

30-Sep-12

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives not designated as hedging contracts:

Energy commodity derivative contracts

Natural gas sales

$

(91

)

$

—

$

(375

)

$

—

Credit Risk

TEP has counterparty credit risk as a result of their use of financial 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 anticipate a material adverse effect on our 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 a financial institution with an investment grade credit rating. 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. The maximum potential exposure to credit losses on TEP’s derivative contracts at September 30, 2013 was:

Asset Position

(in thousands)

Gross exposure

$

24

Netting agreement impact

(5

)

Cash collateral held

—

Net exposure

$

19

In addition, in conjunction with the purchase of exchange-traded derivative contracts, or 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. As of September 30, 2013 and December 31, 2012, TEP did not have any outstanding letters of credit in support of its hedging of commodity price risks associated with the sale of natural gas. As of September 30, 2013 and December 31, 2012, TEP had no margin deposits with counterparties associated with energy commodity contract positions. TEP also has agreements with certain counterparties to its derivative contracts that contain provisions requiring it to post additional collateral upon a decrease in its credit rating. As of September 30, 2013, TEP had no derivative instruments with credit-risk-related contingent features in a net liability position and would not have to post additional collateral if a downgrade was triggered.

Fair Value

Derivative assets and liabilities are measured and reported at fair value. Derivative contracts can be exchange-traded or traded 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 as well as 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, and 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 as of September 30, 2013 and December 31, 2012 based on the fair value hierarchy established by the Codification:

Asset 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 September 30, 2013

Energy commodity derivative contracts

$

24

$

—

$

24

$

—

TEP as of December 31, 2012

Energy commodity derivative contracts

$

224

$

—

$

224

$

—

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 September 30, 2013

Energy commodity derivative contracts

$

5

$

—

$

5

$

—

TEP as of December 31, 2012

Energy commodity derivative contracts

$

23

$

—

$

23

$

—

The table below provides a summary of changes in the fair value of TEP and TEP Pre-Predecessor’s significant unobservable inputs (Level 3) energy commodity derivative contracts:

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30,

September 30, 2012

September 30, 2013

September 30, 2012

2013

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives – net asset (liability):

Beginning of period

$

—

$

—

$

—

$

(352

)

Total gains or (losses)

Included in other comprehensive income

—

—

—

(62

)

Settlements

—

—

—

157

Transfers out of Level 3

—

—

—

257

End of period

$

—

$

—

$

—

$

—

The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to assets held at the reporting date

$

—

$

—

$

—

$

—

During the nine months ended September 30, 2012, derivative liabilities with a fair value of $257,000 were transferred from Level 3 to Level 2 as the level of observable inputs used to value those instruments was deemed to be significant.

Longterm_Debt

Long-term Debt	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Long-term Debt	'
	9	Long-term Debt
	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. The term loan matures on November 13, 2018 and bears interest at a variable rate equal to a reserve adjusted Eurodollar rate + 4.00%, subject to a LIBOR floor of 1.25%, or an alternate base rate + 3.00%. During the three months ended March 31, 2013, TD elected the reserve adjusted Eurodollar rate + 4.00% rate, however, on April 30, 2013 the $400 million of the term loan allocated to TEP was converted to the alternate base rate + 3.00%. As discussed in Note 3 – Business Combinations, $400 million of the term loan, along with the corresponding discount and deferred financing costs, was allocated to TEP on 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 Offering on May 17, 2013, TEP legally assumed the previously allocated $400 million portion of the TD term loan and used a portion of the Offering proceeds, along with borrowings under TEP’s new $500 million credit agreement effective May 17, 2013, 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 nine months ended September 30, 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.
	New Revolving Credit Facility
	On May 17, 2013, in connection with the Offering, TEP entered into a $500 million senior secured revolving credit facility with Barclays Bank PLC, as administrative agent, and a syndicate of lenders (“the revolving credit facility”), which will mature on May 17, 2018. On the closing date of the Offering, TEP borrowed $231.0 million under the credit facility, the proceeds of which were used to (i) repay the approximately $104.1 million of debt assumed from TD that remained after payment of a portion of the assumed debt with proceeds from the Offering; (ii) pay a distribution to TD of $31.2 million equal to the net proceeds from the exercise of the underwriter’s overallotment option to purchase additional common units; (iii) pay $85.5 million to TD as reimbursement for a portion of the capital expenditures made by TD to purchase the contributed assets and (iv) pay origination fees related to the new revolving credit facility and certain other fees associated with the Offering, and fund working capital requirements of TEP. The remaining commitments under the credit facility are available to provide for capital expenditures, permitted acquisitions, working capital needs and for other general partnership purposes. The credit facility has an accordion feature that will allow TEP to increase the available revolving borrowings under the credit facility by up to an additional $100 million, subject to TEP’s receipt of increased or new commitments from lenders and satisfaction of certain other conditions. In addition, the credit facility includes a sublimit up to $40 million for swing line loans and a sublimit up to $50 million for letters of credit. As of September 30, 2013, TEP had outstanding borrowings of $226.0 million and had issued letters of credit totaling $0.7 million.
	TEP’s obligations under the credit facility are (i) guaranteed by TEP and each of its existing and subsequently acquired or organized direct or indirect wholly-owned domestic subsidiaries, subject to TEP’s ability to designate certain of its subsidiaries as “Unrestricted Subsidiaries” and (ii) secured by a first priority lien on substantially all of the present and after acquired property owned by TEP and each guarantor (other than real property interests related to TEP’s pipelines).
	The credit facility contains various covenants and restrictive provisions that, among other things, limits or restricts 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 therefrom), 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.” In addition, 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 are required. As of September 30, 2013, TEP is in compliance with the covenants required under the revolving credit facility.
	Borrowings under the credit facility bear interest, at TEP’s option, at either (a) a base rate, which is a rate equal to the greatest of (i) the prime rate, (ii) the U.S. federal funds rate plus 0.5% or (iii) a one-month reserve adjusted Eurodollar rate plus 1.00%, in each case, plus an applicable margin, or (b) a reserve adjusted Eurodollar rate, plus an applicable margin. Swing line loans bear interest at the base rate plus an applicable margin. For borrowings bearing interest based on the base rate, the applicable margin is initially 1.00%, and for loans bearing interest based on the reserve adjusted Eurodollar rate, the applicable margin is initially 2.00%. After September 30, 2013, the applicable margin will range from 1.00% to 2.00% for base rate borrowings and from 2.00% to 3.00% for reserve adjusted Eurodollar rate borrowings, based upon TEP’s total leverage ratio. The unused portion of the credit facility is subject to a commitment fee, which is initially 0.375%, and after September 30, 2013, is either 0.375% or 0.500%, based on TEP’s total leverage ratio. As of September 30, 2013, the weighted average interest rate on outstanding borrowings was 2.21%.
	TEP’s long-term debt consisted of the following at September 30, 2013 and December 31, 2012:
			September 30, 2013		December 31, 2012
			(in thousands)
	Borrowings under revolving credit facility		$	226,000	$	—
	Term loan due 2018 (allocated from TD)			—		400,000
	Unamortized discount			—		(5,509	)
	Total principal			226,000		394,491
	Current maturities			—		(4,000	)
	Total long-term debt		$	226,000	$	390,491
	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 September 30, 2013 and December 31, 2012, 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)
	30-Sep-13		$	—	$	226,000		$	—	$	226,000	$	226,000
	31-Dec-12		$	—	$	404,000		$	—	$	404,000	$	394,491
	The long-term debt borrowed under the revolving credit facility and the term loan allocated from TD were carried at amortized cost. As of September 30, 2013, the fair value approximates the carrying amount for the borrowings under the revolving credit facility using a discounted cash flow analysis. The fair value of the debt allocated from TD at December 31, 2012 was estimated based on quoted market prices. TEP is not aware of any factors that would significantly affect the estimated fair value since September 30, 2013.

Partnership_Equity_and_Distrib

Partnership Equity and Distributions	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Partnership Equity and Distributions	'
	10	Partnership Equity and Distributions
	As discussed in Note 1 – Description of Business, TD completed the acquisition of TEP Pre-Predecessor subsidiary entities on November 13, 2012. On May 17, 2013, in conjunction with the closing of TEP’s initial public offering, TD’s ownership interest in TIGT and TMID was contributed to TEP in exchange for 9,700,000 common and 16,200,000 subordinated units.
	Distributions to Holders of Common Units, Subordinated Units and General Partner Units
	TEP’s partnership agreement requires TEP to distribute its available cash, 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. The first quarterly cash distribution, which was prorated for the period from May 17, 2013 to June 30, 2013, in the amount of $0.1422 per unit, was declared on July 18, 2013 and was paid on August 13, 2013 to unitholders of record on July 31, 2013. A distribution of $0.2975 per unit for the three months ended September 30, 2013 was declared on October 7, 2013 and will be paid on November 13, 2013 to unitholders of record on November 1, 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, each holder of common units must receive the MQD, plus the cumulative amount of any arrearages in the payment of the MQD from prior quarters, before distributions of available cash from operating surplus may be made on the subordinated units.
	Subordinated Units
	All subordinated units are currently held by TD. The principal difference between our 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 plus any cumulative arrearages in MQD from previous quarters. Furthermore, subordinated unitholders are not entitled to receive arrearages in previous quarter 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. The earliest date on which the subordination period may end is June 30, 2014.
	Incentive Distribution Rights
	The GP owns a 2% general partner interest in TEP which is represented by 826,531 general partner units. The GP also owns all of the incentive distribution rights (“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 GP may transfer these rights separately from its general partner interest, subject to restrictions in our 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 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 GP 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 our business (including reserves for our 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 minimum quarterly distribution 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.
	Distributions to TD
	As discussed in Note 2 – Summary of Significant Accounting Policies, prior to May 17, 2013, 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 periodically as equity distributions. Excluding the second quarter cash distributions paid to TD as a common and subordinated unitholder, as discussed above, there were no distributions from TEP to TD for the three months ended September 30, 2013 and net distributions for the nine months ended September 30, 2013 of $118.5 million. The distribution for the nine months ended September 30, 2013 included the $85.5 million to TD related to the contribution of TIGT and TMID to TEP as well as the $31.2 million net proceeds from the exercise of the underwriter’s option to purchase additional common units as part of the Offering. Net distributions from TEP Pre-Predecessor to TD for the three and nine months ended September 30, 2012 were $13.5 million and $53.5 million, respectively.

Net_Income_per_Limited_Partner

Net Income per Limited Partner Unit	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Net Income per Limited Partner Unit	'
	11	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 using the two-class method by dividing net income available to common and subordinated unitholders by the weighted average number of outstanding limited partner units during the period. Net income available to common and subordinated unitholders is defined as the limited partners’ interest in the net income remaining after general partner incentive distributions.
	Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. However, because our Offering was completed on May 17, 2013, the number of units issued following the Offering is utilized for the 2013 periods presented. 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 Offering was completed on May 17, 2013, no income from the three months ended March 31, 2013 is allocated to the limited partner units that were issued on May 17, 2013. Net income per limited partner unit is not applicable for the three and nine months ended September 30, 2012 as no units were outstanding during those periods.
	The following table illustrates the Partnership’s calculation of net income per limited partner unit for the periods indicated:
			Three Months		Nine Months			Period from		Period from
			Ended		Ended			January 1, 2013 to		May 17, 2013 to
			September 30, 2013		September 30, 2013			May 16, 2013		September 30, 2013
			(in thousands, except per unit amounts)
	Net Income (Loss)		$	7,006	$	350		$	6,982	$	(6,632	)
	General partner interest in net income (loss)			140		6,849			6,982		(133	)
	Net income (loss) available to common and subordinated unitholders		$	6,866	$	(6,499	)	$	—	$	(6,499	)
	Basic net loss per common and subordinated unit		$	0.17	$	(0.16	)			$	(0.16	)
	Diluted net loss per common and subordinated unit		$	0.17	$	(0.16	)			$	(0.16	)
	Basic average number of common and subordinated units outstanding			40,500		40,417					40,417
	Equity Participation Unit equivalent units			363		—					—
	Diluted average number of common and subordinated units outstanding			40,863		40,417					40,417
	The calculation of the basic and diluted net income per common and subordinated unit are the same for the current period as distributable cash flow is greater than the reported net income (loss).
	The calculation of diluted net loss per common and subordinated unit for the nine months ended September 30, 2013 excluded approximately 1.5 million Equity Participation Units (“EPUs”) outstanding at September 30, 2013 that could potentially dilute net income per common and subordinated unit in the future. These EPUs were not included in the computation of diluted net income per common and subordinated unit for the nine months ended September 30, 2013 because their impact would be anti-dilutive given the reported net loss to common and subordinated unitholders. Had TEP generated net income available to common and subordinated unitholders in the nine months ended September 30, 2013, approximately 933,000 potential common units related to the EPUs would have been included in diluted average units outstanding. See Note 13 – Equity-Based Compensation for additional information regarding the EPUs.

Reporting_Segments

Reporting Segments	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Reporting Segments	'
	12	Reporting Segments
	Our 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 interstate natural gas pipelines and related natural gas storage facilities that provide services to third-party natural gas distribution utilities and other shippers.
	Processing
	The Processing segment is engaged in ownership and operation of natural gas processing and treating facilities that produce NGLs and residue gas that is sold in local wholesale markets or delivered into pipelines for transportation to additional end markets.
	Corporate and Other
	Corporate and Other includes corporate overhead costs incurred subsequent to the Offering on May 17, 2013 which are not directly associated with the operations of our reportable segments, such as interest and fees associated with our 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.
	Prior to the second quarter of 2013, the Predecessor Entities considered operating income to be its primary segment performance measure. Beginning in the second quarter of 2013, TEP began using Adjusted EBITDA as its primary segment performance measure as it provides a more 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 before 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 disposals and gains or losses on the repurchase, redemption or early retirement of debt.
	The following tables set forth TEP and TEP Pre-Predecessor’s segment information for the periods indicated:
			TEP									TEP Pre-Predecessor
			Three Months Ended September 30, 2013									Three Months Ended September 30, 2012
			Total			Inter-			External			Total		Inter-			External
			Revenue			Segment			Revenue			Revenue		Segment			Revenue
			(in thousands)									(in thousands)
	Gas transportation and storage		$	26,434		$	(151	)	$	26,283		$	31,091	$	(184	)	$	30,907
	Processing			36,976			—			36,976			33,571		—			33,571
	Corporate and other			—			—			—			—		—			—
	Total revenue		$	63,410		$	(151	)	$	63,259		$	64,662	$	(184	)	$	64,478
			TEP									TEP Pre-Predecessor
			Nine Months Ended September 30, 2013									Nine Months Ended September 30, 2012
			Total			Inter-			External			Total		Inter-			External
			Revenue			Segment			Revenue			Revenue		Segment			Revenue
			(in thousands)									(in thousands)
	Gas transportation and storage		$	77,920		$	(521	)	$	77,399		$	90,637	$	(597	)	$	90,040
	Processing			109,520			—			109,520			100,486		—			100,486
	Corporate and other			—			—			—			—		—			—
	Total revenue		$	187,440		$	(521	)	$	186,919		$	191,123	$	(597	)	$	190,526
			TEP									TEP Pre-Predecessor
			Three Months Ended September 30, 2013									Three Months Ended September 30, 2012
			Total			Inter-			External			Total		Inter-			External
			Adjusted			Segment			Adjusted			Adjusted		Segment			Adjusted
			EBITDA						EBITDA			EBITDA					EBITDA
			(in thousands)									(in thousands)
	Gas transportation and storage		$	13,733		$	(151	)	$	13,582		$	14,677	$	(184	)	$	14,493
	Processing			3,644			151			3,795			3,711		184			3,895
	Corporate and other			(632	)		—			(632	)		—		—			—
	Reconciliation to Income (Loss) before Income Taxes:
	Interest expense (income), net									1,422								(1,446	)
	Texas Margin Taxes									—								20
	Depreciation and amortization expense									7,342								5,949
	Non-cash loss related to
	derivative instruments									112								—
	Non-cash compensation expense									863								—
	Income before income taxes								$	7,006							$	13,865
			TEP									TEP Pre-Predecessor
			Nine Months Ended September 30, 2013									Nine Months Ended September 30, 2012
			Total			Inter-			External			Total		Inter-			External
			Adjusted			Segment			Adjusted			Adjusted		Segment			Adjusted
			EBITDA						EBITDA			EBITDA					EBITDA
			(in thousands)									(in thousands)
	Gas transportation and storage		$	37,043		$	(521	)	$	36,522		$	45,603	$	(597	)	$	45,006
	Processing			15,713			521			16,234			15,536		597			16,133
	Corporate and other			(939	)		—			(939	)		—		—			—
	Reconciliation to Income (Loss) before Income Taxes:
	Interest expense (income), net									10,486								(1,446	)
	Texas Margin Taxes									—								193
	Depreciation and amortization expense									22,324								17,776
	Loss on extinguishment of debt									17,526								—
	Non-cash loss related to derivative instruments									183								—
	Non-cash compensation expense									948								—
	Income before income taxes								$	350							$	44,616
		TEP
		Total Assets
		September 30, 2013			December 31, 2012
		(in thousands)
Gas transportation and storage		$	706,218		$	741,595
Processing			312,998			294,219
Corporate and other			7,020			—
Total assets		$	1,026,236		$	1,035,814

EquityBased_Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 30, 2013
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Equity-Based Compensation	'
	13	Equity-Based Compensation
	Long-term Incentive Plan
	Effective May 13, 2013, our 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. Vesting and forfeiture requirements are at the discretion of the Board of Directors of our general partner at the time of the grant.
	Equity Participation Units
	On June 26, 2013, our general partner approved the grant of up to 1.5 million equity participation units (“EPUs”) under the LTIP. Effective the same date, 1.49 million EPUs were granted to employees and directors of our general partner and its affiliates. Vesting of the EPUs is contingent upon the Pony Express Pipeline Conversion Project (see Note 14 – Regulatory Matters) being placed in service and will occur in two parts, with one-third vesting on the later of the Pony Express in-service date or May 13, 2015, and remaining two-thirds vesting on the later of the Pony Express in-service date or May 13, 2017. If the Pony Express Pipeline project has not been placed in service by May 13, 2018, the EPUs will expire and no vesting of the EPUs will occur.
	The EPU grants under the LTIP plan are measured at their grant date fair value. The EPUs are non-participating, 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 dividends during the vesting period. Total equity-based compensation cost related to the EPU grants of approximately $2.0 million and $2.1 million was recognized during the three and nine months ended September 30, 2013, respectively. Of the total compensation cost, $0.9 million and $1.0 million was recognized as compensation expense at TEP for the three and nine month periods ending September 30, 2013 and the remainder was allocated to TD. As of September 30, 2013, $19.6 million of total compensation cost related to non-vested EPUs is expected to be recognized over a weighted-average period of 2.9 years, a portion of which will be charged as expense to TD.
	The following table summarizes the changes in the EPUs outstanding for the three and nine months ended September 30, 2013:
			Three Months Ended September 30, 2013						Nine Months Ended September 30, 2013
			Shares			Weighted Average			Shares			Weighted Average
						Grant Date Fair Value						Grant Date Fair Value
	Beginning of period		$	1,490,000		$	17.49		$	—		$	—
	Granted			5,500			18.92			1,495,500			17.49
	Forfeited			(29,500	)		(17.49	)		(29,500	)		(17.49	)
	End of period		$	1,466,000		$	17.49		$	1,466,000		$	17.49

Regulatory_Matters

Regulatory Matters	9 Months Ended
	Sep. 30, 2013
Text Block [Abstract]	'
Regulatory Matters	'
	14	Regulatory Matters
	TIGT
	Pony Express Pipeline Conversion Project – 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 transfer to an affiliate, PXP, for the purpose of converting the facilities into crude oil pipeline facilities; and (2) construct and operate certain replacement-type facilities necessary to continue service to existing natural gas firm transportation customers following the proposed conversion. We refer to this project as the Pony Express Pipeline Conversion Project. The FERC abandonment does not constitute an abandonment for accounting purposes. Pursuant to the terms of the Purchase and Sale Agreement filed in this docket and cited by FERC in approving the Conversion Project, PXP will reimburse TIGT for the net book value of the natural gas pipeline facilities plus other TIGT incurred costs required to construct gas replacement facilities and to arrange substitute gas transportation services to certain TIGT shippers.
	The Pony Express Pipeline Conversion Project, upon FERC approval and implementation, 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. Such application, upon approval by the FERC, will authorize the reconversion of a portion of the Pony Express Pipeline back to the transportation of crude oil as it was prior to 1997. By order issued September 12, 2013, TIGT was granted authorization to abandon the Pony Express Assets and construct the Pony Express Pipeline Conversion Project facilities. On October 7, 2013 TIGT commenced the mobilization of personnel and equipment for the construction of the project facilities necessary to complete the Pony Express Pipeline Conversion Project to continue service to existing TIGT customers.

Legal_and_Environmental_Matter

Legal and Environmental Matters	9 Months Ended
	Sep. 30, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Legal and Environmental Matters	'
	15	Legal and Environmental Matters
	Legal
	Other than the matters discussed below, TEP is a defendant in various lawsuits arising from the day-to-day operations of their 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 records a liability for litigation and claims when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. TEP has evaluated claims in accordance with the accounting guidance for contingencies that it deems both probable and reasonably estimable and, accordingly, recorded no reserve for claims as of September 30, 2013. TEP recorded aggregate reserves for all claims of approximately $0.1 million as of December 31, 2012. This reserve is reported on the accompanying Condensed Combined Balance Sheets within “other accrued liabilities.”
	TMID
	West Frenchie Draw
	TMID was a party to the following legal actions pertaining to its West Frenchie Draw treating plant:
	Elkhorn Construction, Inc. v. KM Upstream LLC and Newpoint Gas Services, Inc., Civil Action No. 36823 in the District Court of Fremont County, Wyoming (9th Judicial District) (the “Trial Court Action”); Elkhorn Construction, Inc. v. KM Upstream LLC, Appeal No. S-11-0186 and S-11-0208 in the Wyoming Supreme Court (the “Appeal”); In Re: Newpoint Gas, L.P., Case No. 10-16104 in the U.S. Bankruptcy Court for the Western District of Oklahoma (Oklahoma City) (“the Newpoint Bankruptcy”).
	Elkhorn Construction, Inc., (“Elkhorn”) a sub-contractor to Newpoint Gas Services, Inc. (“Newpoint Gas Services”) filed suit on March 23, 2009 in Fremont County, Wyoming to enforce liens against TMID arising in connection with the West Frenchie Draw Amine Plant in the principal amount of approximately $4.9 million plus interest, late charges, attorney’s fees and costs from January 16, 2009. On November 24, 2009, Newpoint Gas Services was added to the litigation as a defendant. TMID and Newpoint Gas Services filed cross-claims against each other. On September 21, 2012, TMID paid the adjudicated portion of Elkhorn’s mechanics lien of $4.7 million plus 7% interest from the date of the lien for a total payment of $5.9 million. On April 30, 2013, the Court awarded Elkhorn additional principal and interest (including post-judgment interest) on its mechanic’s lien claim. On May 30, 2013, TMID paid approximately $0.2 million to satisfy the remaining portion of Elkhorn’s mechanic’s lien claim. On June 12, 2013, the Court granted Elkhorn’s motion for summary judgment seeking enforcement and foreclosure of its oil and gas lien claim, which provides for the recovery of attorney’s fees and costs by Elkhorn.
	Newpoint Gas L.P. (“Newpoint LP”), a closely held affiliate of Newpoint Gas Services, commenced the above-referenced bankruptcy court case under Chapter 7 of the Bankruptcy Code. TMID filed an adversary proceeding in the bankruptcy action seeking to consolidate the assets and liabilities of Newpoint Gas Services with Newpoint LP. The judge issued an order dismissing the adversary proceeding on June 10, 2013 based on a finding that the Trustee was the only party with standing to seek substantive consolidation. TMID’s claim in the bankruptcy case has been withdrawn.
	In August of 2013, the Company fully and finally settled all legal actions with Newpoint Gas Services and Elkhorn. In exchange for cash settlement payments from TMID, the parties released and dismissed all claims against each other with prejudice.
	ConocoPhillips Off-Spec Product Deliveries
	In April and May of 2009, TMID delivered to ConocoPhillips NGL product that was alleged by a ConocoPhillips affiliate to contain fluoride levels that exceeded contract tolerances. In February 2012, TMID paid $1.1 million to settle this issue with the affiliated refinery that received the product from ConocoPhillips. TMID recognized the full settlement amount of $1.1 million in 2009. In 2012, TMID recovered $350,000 from two parties who delivered the contested product to TMID and this matter is now concluded.
	TIGT
	Cornhusker Energy Lexington Plant Explosion
	TIGT is the defendant in a lawsuit pending in state court in Douglas County, Nebraska (CI 10 9387384). Plaintiffs in the suit are Cornhusker Energy Lexington, LLC and its insurer, National Union Fire Insurance Company of Pittsburgh, Pennsylvania. The suit was initiated in February 2010. Plaintiffs allege that Cornhusker received natural gas that was transported on the TIGT System that did not meet required pipeline specifications, and as a result Cornhusker’s ethanol plant suffered an explosion and subsequent fire. Plaintiffs complaint requests monetary relief, attorney’s fees, costs and interest of approximately $3.9 million; however in connection with mediation in May 2013, Plaintiffs increased the amount of their alleged damages in a statement to the mediator. Although we believe Cornhusker’s claims to be without merit, TD has agreed to indemnify TIGT for any settlement of damage award in excess of the $3.9 million, pursuant to an Omnibus Agreement between TD and TEP, among others. A trial date has been set by the Court for November 2013.
	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. The failures both 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; such costs related to the Goshen County failure are not currently believed to be material. The scope and cost of any additional investigation and remediation activities are currently being evaluated.
	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 their 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 had recorded environmental accruals of $3.5 million at September 30, 2013 and December 31, 2012.
	TMID
	Casper and Douglas Plants, United States Environmental Protection Agency Notice of Violation
	In March 2011, the United States Environmental Protection Agency (“U.S. EPA”) and the Wyoming Department of Environmental Quality (“WDEQ”) conducted an inspection at the Douglas and Casper Gas Plants in Wyoming. In June 2011, TMID received two letters from the U.S. EPA alleging violations at both gas plants of the Risk Management Program requirements under the Clean Air Act. TMID has executed Combined Complaint and Consent Agreements with the U.S. EPA, including monetary penalties of $158,000 for each facility, to resolve these allegations, which were approved by the U.S. EPA in September 2012.
	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. In April 2013, TMID received a letter from the U.S. EPA concerning settlement of this matter. Settlement negotiations with the U.S. EPA are continuing, including 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.

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	16	Subsequent Events
	On October 1, 2013, TIGT received a payment from TD, on behalf of PXP, in the amount of $84.9 million in connection with the expected sale of the Pony Express Assets, the proceeds of which were used to repay $85.0 million of borrowings under the revolving credit facility. For additional information regarding the sale of the Pony Express Assets, see Note 14 – Regulatory Matters.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	These unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2013 and the unaudited condensed combined financial statements for the three and nine months ended September 30, 2012 have been prepared in accordance with 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 nine months ended September 30, 2013 and the unaudited condensed combined financial statements for the three and nine months ended September 30, 2012 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.
	Our financial results for the three and nine months ended September 30, 2013 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2013. These unaudited condensed consolidated financial statements should be read in conjunction with our combined financial statements and notes thereto included in our final prospectus dated May 13, 2013 (the “Prospectus”) and filed with the Securities Exchange Commission (the “SEC”) pursuant to Rule 424 on May 14, 2013.
	The accompanying unaudited condensed consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to us by TD in connection with the Offering for the periods prior to May 17, 2013, the closing date of TEP’s Offering, 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 transfer 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.
	The condensed combined financial statements of the Predecessor Entities include legal entities, as detailed above, that are indirect wholly-owned subsidiaries of the Predecessor Entities. As the condensed combined financial statements reflect TEP Predecessor and TEP Pre-Predecessor as single entities, significant intra-entity items have been eliminated in the presentation. Net equity distributions of the Predecessor Entities included in the Condensed Combined Statements of Equity and Condensed Combined Statements of Cash Flows represent transfers of cash as a result of TD and TEP Pre-Predecessor Parent’s centralized cash management systems prior to May 17, 2013, 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.
	TEP’s financial results as presented on the condensed consolidated statements of income, comprehensive income and cash flows have been separated from TEP Pre-Predecessor’s financial results by a bold vertical black line.
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 or the Predecessor Entities’ 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.
New Accounting Pronouncements Adopted	'
	New Accounting Pronouncements Adopted
	ASU No. 2011-11, Balance Sheet (Topic 210), “Disclosures about Offsetting Assets and Liabilities” and ASU No. 2013-01, Balance Sheet (Topic 210), “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities”
	On December 16, 2011, the FASB issued ASU No. 2011-11, Balance Sheet (Topic 210), “Disclosures about Offsetting Assets and Liabilities”. ASU 2011-11 requires entities to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. In January 2013, the FASB issued ASU No. 2013-01, Balance Sheet (Topic 210), “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities,” which clarifies that the scope of ASU No. 2011-11 applies to derivatives accounted for in accordance with the Codification guidance for derivatives and hedging transactions, including bifurcated embedded derivatives, repurchase agreements and reverse purchase agreements, and certain securities borrowing and securities lending transactions. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The adoption of ASU 2011-11 on January 1, 2013 did not have a material impact on TEP’s financial statements.
	ASU No. 2013-02, Comprehensive Income (Topic 220), “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”
	In February 2013, the FASB issued ASU No. 2013-02, Comprehensive Income (Topic 220), “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”. ASU 2013-02 does not change the current requirements for reporting net income or other comprehensive income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component, either on the face of the statement where net income is presented or in the notes, depending on whether or not the amount reclassified is required under GAAP to be reclassified to net income in its entirety in the same reporting period. ASU 2013-02 is effective for public entities prospectively for reporting periods beginning after December 15, 2012, or January 1, 2013 for TEP. The adoption of ASU 2013-02 did not have a material impact on TEP’s financial statements.

Business_Combinations_Tables

Business Combinations (Tables)	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
Pro Forma Revenue and Net Income Including Adjustments	'
			TEP Pre-Predecessor
			Three Months		Nine Months
			Ended		Ended
			September 30, 2012		September 30, 2012
			(in thousands)
	Revenue		$	64,478	$	190,526
	Net income		$	6,497	$	22,512
	Pro forma revenue contains no adjustments to the historical amounts. Pro forma net income includes adjustments for the three and nine months ended September 30, 2012 to give effect to the following:
		(a)	Reduction in net income to reflect additional depreciation expense associated with the increase in the cost of property, plant and equipment that resulted from the allocation of the purchase price to the fair value of the assets and liabilities acquired by TD.
		(b)	Reduction in net income to reflect interest expense on the long-term debt allocated to TIGT and TMID in connection with the acquisition of TIGT and TMID by TD.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Schedule of Transactions with Affiliated Companies	'
	Totals of transactions with affiliated companies are as follows:
			TEP					TEP Pre-Predecessor		TEP			TEP Pre-Predecessor
			Three Months					Three Months		Nine Months			Nine Months
			Ended					Ended		Ended			Ended
			September 30,					September 30,		September 30,			September 30,
			2013					2012		2013			2012
			(in thousands)					(in thousands)		(in thousands)			(in thousands)
	Cost of sales and transportation services		$	1,119				$	680	$	1,016		$	4,313
	Charges to TEP and TEP Pre-Predecessor: (1)
	Property, plant and equipment, net		$	140				$	153	$	4,979		$	990
	Other deferred charges		$	6				$	49	$	1,098		$	106
	Operation and maintenance		$	3,863				$	3,721	$	11,461		$	11,575
	General and administrative		$	6,006	(2)			$	3,038	$	15,594	(2)	$	7,740
	(1)	Charges to TEP and TEP Pre-Predecessor include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three and nine months ended September 30, 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in a single allocated amount for general and administrative costs rather than individual charges as in prior periods.
Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Combined Balance Sheets	'
	Details of balances with affiliates included in “Accounts receivable” and “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
			September 30, 2013			December 31, 2012
			(in thousands)
	Accounts receivable from affiliated companies:
	Tallgrass Operations, LLC		$	—		$	6,244
	Rockies Express Pipeline LLC			1,672			219
	Total accounts receivable from affiliated companies		$	1,672		$	6,463
	Payables to affiliated companies:
	Note payable to TD		$	—		$	1,381
	Interest payable to TD			—			6
	Accounts payable to Tallgrass Operations, LLC			1,307			—
	Accounts payable to Rockies Express Pipeline LLC			46			—
	Total payables to affiliated companies		$	1,353		$	1,387

Inventory_Tables

Inventory (Tables)	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Schedule of Components of Inventory	'
	The components of inventory at September 30, 2013 and December 31, 2012 consisted of the following:
		September 30, 2013		December 31, 2012
		(in thousands)
	Materials and supplies	$	1,606	$	1,567
	Natural gas liquids		770		637
	Gas in underground storage		294		—
	Total inventory	$	2,670	$	2,204

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2013
Property Plant And Equipment [Abstract]	'
Components of Property Plant and Equipment	'
	The components of property, plant and equipment at September 30, 2013 and December 31, 2012 consisted of the following:
		September 30, 2013			December 31, 2012
		(in thousands)
	Natural gas pipelines	$	421,756		$	421,644
	Processing and treating assets		199,743			195,108
	Buildings		15,518			15,518
	Vehicles		3,239			3,138
	Gas in underground storage		1,768			2,345
	Land		1,534			1,534
	General and other		1,218			1,207
	Construction work in progress		52,106			32,932
	Accumulated depreciation and amortization		(25,162	)		(3,950	)
	Total property, plant and equipment, net	$	671,720		$	669,476

Risk_Management_Tables

Risk Management (Tables)

9 Months Ended

Sep. 30, 2013

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

September 30, 2013

December 31, 2012

Location

(in thousands)

Energy commodity derivative contracts

Current assets

$

24

$

224

Total derivative assets

$

24

$

224

Balance Sheet

30-Sep-13

31-Dec-12

Location

(in thousands)

Energy commodity derivative contracts

Current liabilities

$

5

$

23

Total derivative liabilities

$

5

$

23

Derivative Contracts Included in Combined Statements of Income

'

The following tables summarize the impact of derivative contracts for the three and nine months ended September 30, 2013 and 2012:

Amount of gain/(loss) recognized in OCI on derivatives (effective portion)

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

September 30, 2012

September 30, 2013

September 30, 2012

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives in cash flow hedging relationships:

Energy commodity derivative contracts

$

—

$

(366

)

$

—

$

978

Amount of (gain)/loss reclassified from Accumulated OCI into  income (effective portion)

Location of gain/

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

(loss) reclassified

from AOCI

into income

(effective portion)

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

30-Sep-12

30-Sep-13

30-Sep-12

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives in cash flow hedging relationships:

Energy commodity derivative contracts

Natural gas sales

$

—

$

1,584

$

—

$

3,535

Amount of gain/(loss) recognized in income on derivatives

Location of gain/

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

(loss) recognized

in income on

derivative

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

30-Sep-12

30-Sep-13

30-Sep-12

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives not designated as hedging contracts:

Energy commodity derivative contracts

Natural gas sales

$

(91

)

$

—

$

(375

)

$

—

Maximum Potential Exposure to Credit Losses on TEP's Derivative Contracts

'

The maximum potential exposure to credit losses on TEP’s derivative contracts at September 30, 2013 was:

Asset Position

(in thousands)

Gross exposure

$

24

Netting agreement impact

(5

)

Cash collateral held

—

Net exposure

$

19

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 as of September 30, 2013 and December 31, 2012 based on the fair value hierarchy established by the Codification:

Asset 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 September 30, 2013

Energy commodity derivative contracts

$

24

$

—

$

24

$

—

TEP as of December 31, 2012

Energy commodity derivative contracts

$

224

$

—

$

224

$

—

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 September 30, 2013

Energy commodity derivative contracts

$

5

$

—

$

5

$

—

TEP as of December 31, 2012

Energy commodity derivative contracts

$

23

$

—

$

23

$

—

Schedule of Energy Commodity Derivative Contracts

'

The table below provides a summary of changes in the fair value of TEP and TEP Pre-Predecessor’s significant unobservable inputs (Level 3) energy commodity derivative contracts:

TEP

TEP Pre-Predecessor

TEP

TEP Pre-Predecessor

Three Months

Three Months

Nine Months

Nine Months

Ended

Ended

Ended

Ended

September 30, 2013

September 30, 2012

September 30, 2013

September 30, 2012

(in thousands)

(in thousands)

(in thousands)

(in thousands)

Derivatives - net asset (liability):

Beginning of period

$

—

$

—

$

—

$

(352

)

Total gains or (losses)

Included in other comprehensive income

—

—

—

(62

)

Settlements

—

—

—

157

Transfers out of Level 3

—

—

—

257

End of period

$

—

$

—

$

—

$

—

The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to assets held at the reporting date

$

—

$

—

$

—

$

—

Longterm_Debt_Tables

Long-term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Summary of Long Term Debt	'
	TEP’s long-term debt consisted of the following at September 30, 2013 and December 31, 2012:
		September 30, 2013		December 31, 2012
		(in thousands)
	Borrowings under revolving credit facility	$	226,000	$	—
	Term loan due 2018 (allocated from TD)		—		400,000
	Unamortized discount		—		(5,509	)
	Total principal		226,000		394,491
	Current maturities		—		(4,000	)
	Total long-term debt	$	226,000	$	390,491
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 September 30, 2013 and December 31, 2012, 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)
	30-Sep-13	$	—	$	226,000		$	—	$	226,000	$	226,000
	31-Dec-12	$	—	$	404,000		$	—	$	404,000	$	394,491

Net_Income_per_Limited_Partner1

Net Income per Limited Partner Unit (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Summary of Net Income Per Limited Partner Unit	'
	The following table illustrates the Partnership’s calculation of net income per limited partner unit for the periods indicated:
		Three Months		Nine Months			Period from		Period from
		Ended		Ended			January 1, 2013		May 17, 2013
		September 30, 2013		September 30, 2013			to May 16, 2013		to September 30, 2013
		(in thousands, except per unit amounts)
	Net Income (Loss)	$	7,006	$	350		$	6,982	$	(6,632	)
	General partner interest in net income (loss)		140		6,849			6,982		(133	)
	Net income (loss) available to common and subordinated unitholders	$	6,866	$	(6,499	)	$	—	$	(6,499	)
	Basic net loss per common and subordinated unit	$	0.17	$	(0.16	)			$	(0.16	)
	Diluted net loss per common and subordinated unit	$	0.17	$	(0.16	)			$	(0.16	)
	Basic average number of common and subordinated units outstanding		40,500		40,417					40,417
	Equity Participation Unit equivalent units		363		—					—
	Diluted average number of common and subordinated units outstanding		40,863		40,417					40,417

Reporting_Segments_Tables

Reporting Segments (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Summary of TEP and TEP Pre-Predecessor's Segment Information	'
	The following tables set forth TEP and TEP Pre-Predecessor’s segment information for the periods indicated:
		TEP									TEP Pre-Predecessor
		Three Months Ended September 30, 2013									Three Months Ended September 30, 2012
		Total			Inter-			External			Total		Inter-			External
		Revenue			Segment			Revenue			Revenue		Segment			Revenue
		(in thousands)									(in thousands)
	Gas transportation and storage	$	26,434		$	(151	)	$	26,283		$	31,091	$	(184	)	$	30,907
	Processing		36,976			—			36,976			33,571		—			33,571
	Corporate and other		—			—			—			—		—			—
	Total revenue	$	63,410		$	(151	)	$	63,259		$	64,662	$	(184	)	$	64,478
		TEP									TEP Pre-Predecessor
		Nine Months Ended September 30, 2013									Nine Months Ended September 30, 2012
		Total			Inter-			External			Total		Inter-			External
		Revenue			Segment			Revenue			Revenue		Segment			Revenue
		(in thousands)									(in thousands)
	Gas transportation and storage	$	77,920		$	(521	)	$	77,399		$	90,637	$	(597	)	$	90,040
	Processing		109,520			—			109,520			100,486		—			100,486
	Corporate and other		—			—			—			—		—			—
	Total revenue	$	187,440		$	(521	)	$	186,919		$	191,123	$	(597	)	$	190,526
		TEP									TEP Pre-Predecessor
		Three Months Ended September 30, 2013									Three Months Ended September 30, 2012
		Total			Inter-			External			Total		Inter-			External
		Adjusted			Segment			Adjusted			Adjusted		Segment			Adjusted
		EBITDA						EBITDA			EBITDA					EBITDA
		(in thousands)									(in thousands)
	Gas transportation and storage	$	13,733		$	(151	)	$	13,582		$	14,677	$	(184	)	$	14,493
	Processing		3,644			151			3,795			3,711		184			3,895
	Corporate and other		(632	)		—			(632	)		—		—			—
	Reconciliation to Income (Loss) before Income Taxes:
	Interest expense (income), net								1,422								(1,446	)
	Texas Margin Taxes								—								20
	Depreciation and amortization expense								7,342								5,949
	Non-cash loss related to
	derivative instruments								112								—
	Non-cash compensation expense								863								—
	Income before income taxes							$	7,006							$	13,865
		TEP									TEP Pre-Predecessor
		Nine Months Ended September 30, 2013									Nine Months Ended September 30, 2012
		Total			Inter-			External			Total		Inter-			External
		Adjusted			Segment			Adjusted			Adjusted		Segment			Adjusted
		EBITDA						EBITDA			EBITDA					EBITDA
		(in thousands)									(in thousands)
	Gas transportation and storage	$	37,043		$	(521	)	$	36,522		$	45,603	$	(597	)	$	45,006
	Processing		15,713			521			16,234			15,536		597			16,133
	Corporate and other		(939	)		—			(939	)		—		—			—
	Reconciliation to Income (Loss) before Income Taxes:
	Interest expense (income), net								10,486								(1,446	)
	Texas Margin Taxes								—								193
	Depreciation and amortization expense								22,324								17,776
	Loss on extinguishment of debt								17,526								—
	Non-cash loss related to derivative instruments								183								—
	Non-cash compensation expense								948								—
	Income before income taxes							$	350							$	44,616
		TEP
		Total Assets
		September 30, 2013			December 31, 2012
		(in thousands)
	Gas transportation and storage	$	706,218		$	741,595
	Processing		312,998			294,219
	Corporate and other		7,020			—
	Total assets	$	1,026,236		$	1,035,814

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2013
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Summarizes Changes in EPUs Outstanding	'
	The following table summarizes the changes in the EPUs outstanding for the three and nine months ended September 30, 2013:
		Three Months Ended September 30, 2013						Nine Months Ended September 30, 2013
		Shares			Weighted Average			Shares			Weighted Average
					Grant Date Fair Value						Grant Date Fair Value
	Beginning of period	$	1,490,000		$	17.49		$	—		$	—
	Granted		5,500			18.92			1,495,500			17.49
	Forfeited		(29,500	)		(17.49	)		(29,500	)		(17.49	)
	End of period	$	1,466,000		$	17.49		$	1,466,000		$	17.49

Description_of_Business_Additi

Description of Business - Additional Information (Detail) (USD $)

1 Months Ended

9 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

17-May-13

Sep. 30, 2013

17-May-13

17-May-13

Sep. 30, 2013

17-May-13

17-May-13

Nov. 13, 2012

17-May-13

Sep. 30, 2013

17-May-13

17-May-13

17-May-13

17-May-13

17-May-13

17-May-13

TIGT [Member]

Tallgrass Midstream LLC [Member]

Limited Partners [Member]

IPO [Member]

IPO [Member]

TEP Predecessor [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

Ownership Interests Held By Public [Member]

Ownership Interests Held By TD [Member]

Common unitholders [Member]

Limited Partners [Member]

Limited Partners [Member]

Miles

Common unitholders [Member]

Subordinated unitholder [Member]

Limited Partners [Member]

IPO [Member]

Maximum [Member]

Organization [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Initial public offering of common units

'

'

'

'

'

14,600,000

'

'

'

'

'

'

'

'

14,600,000

'

Unit price of shares

'

'

'

'

'

$21.50

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Units, Sale of public offering

'

'

'

'

'

1,550,000

1,957,500

'

'

'

'

'

'

'

'

'

Proceeds from sale of common units

'

$290,498,000

'

'

$290,498,000

$295,900,000

'

'

'

'

'

'

'

'

'

'

Additional offering cost

'

'

'

'

'

5,400,000

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of common units net of additional offering cost

'

290,498,000

'

'

'

290,500,000

'

'

'

'

'

'

'

'

'

'

Equity interest percentage

'

'

100.00%

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

Common and subordinated units issued, units

9,700,000

'

'

'

'

'

'

'

'

'

9,700,000

16,200,000

'

'

'

9,700,000

Unissued common units to underwriters

'

'

'

'

'

'

'

'

'

'

407,500

'

'

'

'

'

Long term debt assumed

'

'

'

'

'

'

'

'

400,000,000

'

'

'

'

'

'

'

Reimbursement for a portion of capital expenditures made by related party

'

'

'

'

'

'

'

'

85,500,000

85,500,000

'

'

'

'

'

'

Proceeds from issuance of overallotment units to underwriters

'

'

'

'

'

'

'

'

'

'

'

'

31,200,000

'

'

'

Repayment of debt assumed

'

'

'

'

'

'

'

'

'

'

'

'

'

$295,900,000

'

'

Ownership interest in total equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

63.00%

Limited partners interest in offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36.00%

64.00%

Subordinated unit

16,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

16,200,000

General partner units issued to Tallgrass MLP GP, LLC (the "GP")

826,531

826,531

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partner interest in TEP as well as IDRs

2.00%

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas transmission lines owned

'

'

'

'

'

'

'

5,250

'

'

'

'

'

'

'

'

Gas transmission lines to be sold

'

'

'

'

'

'

'

432

'

'

'

'

'

'

'

'

Business_Combinations_Addition

Business Combinations - Additional Information (Detail) (USD $)	17-May-13	Apr. 30, 2013	Nov. 13, 2012
TEP Predecessor [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Net assets acquired	'	'	$573,200,000
TEP Predecessor [Member] | TD [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Business acquisition cash paid to acquire asset	'	'	1,800,000,000
Business acquisition assumed debt to acquire asset	'	'	1,500,000,000
TEP Predecessor [Member] | TIGT [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Equity interest percentage	'	'	100.00%
TEP Predecessor [Member] | Tallgrass Midstream LLC [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Equity interest percentage	'	'	100.00%
TEP Pre-Predecessor [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Business combination, long-term debt	$400,000,000	$400,000,000	$400,000,000

Business_Combinations_Pro_Form

Business Combinations - Pro Forma Revenue and Net Income Including Adjustments (Detail) (TEP Pre-Predecessor [Member], USD $)	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2012	Sep. 30, 2012
TEP Pre-Predecessor [Member]	'	'
Business Acquisition [Line Items]	'	'
Revenue	$64,478	$190,526
Net income	$6,497	$22,512

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012	17-May-13	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012
			TD [Member]	TD [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Scenario, Forecast [Member]	Scenario [Member]	Affiliated Entity [Member]	Affiliated Entity [Member]
					TEP [Member]	TD [Member]	TD [Member]		Public Company Expense [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Estimated annual expense reimbursement	'	'	'	'	'	'	'	$18,500,000	'	'	'
Expected public company cost reimbursement	'	'	'	'	'	'	'	'	625,000	'	'
Gas imbalance payables	2,287,000	1,250,000	'	'	'	'	'	'	'	900,000	300,000
Other deferred charges	17,729,000	23,066,000	'	'	6,800,000	'	'	'	'	'	'
Reimbursement for a portion of capital expenditures made by related party	'	'	85,500,000	85,500,000	'	4,300,000	4,300,000	'	'	'	'
Reimbursement for a portion of capital expenditures made by related party	'	'	'	'	'	$7,700,000	$7,700,000	'	'	'	'

Related_Party_Transactions_Sch

Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Thousands, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Operation and maintenance [Member]

Operation and maintenance [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Property, plant and equipment, net [Member]

Property, plant and equipment, net [Member]

Property, plant and equipment, net [Member]

Property, plant and equipment, net [Member]

Other deferred charges [Member]

Other deferred charges [Member]

Other deferred charges [Member]

Other deferred charges [Member]

Operation and maintenance [Member]

Operation and maintenance [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of sales and transportation services related to transactions with affiliated companies

$1,119

$1,016

'

'

$680

$4,313

'

'

'

'

'

'

'

'

'

'

Costs Capitalized related to transactions with affiliated companies

'

'

'

'

'

'

'

'

140

4,979

153

990

6

1,098

49

106

Expenses related to transactions with affiliated companies

'

'

3,863

11,461

'

'

3,721

11,575

'

'

'

'

'

'

'

'

General and administrative shared service expenses related to transactions with affiliated companies

$6,006

$15,594

'

'

$3,038

$7,740

'

'

'

'

'

'

'

'

'

'

Related_Party_Transactions_Sch1

Related Party Transactions - Schedule of Balances with Affiliates Included in Accounts Receivable and Accounts Payable in Combined Balance Sheets (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Total accounts receivable from affiliated companies	$1,672	$6,463
Note payable to affiliated companies	'	1,387
Accounts payable to affiliated companies	1,353	'
Total payables to affiliated companies	1,353	1,387
Tallgrass Operations, LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total accounts receivable from affiliated companies	'	6,244
Accounts payable to affiliated companies	1,307	'
Rockies Express Pipeline LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total accounts receivable from affiliated companies	1,672	219
Accounts payable to affiliated companies	46	'
TD [Member]	'	'
Related Party Transaction [Line Items]	'	'
Note payable to affiliated companies	'	1,381
Interest payable to affiliated companies	'	$6

Inventory_Schedule_of_Componen

Inventory - Schedule of Components of Inventory (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Materials and supplies	$1,606	$1,567
Natural gas liquids	770	637
Gas in underground storage	294	'
Total inventory	$2,670	$2,204

Property_Plant_and_Equipment_C

Property Plant and Equipment - Components of Property Plant and Equipment (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation and amortization	($25,162)	($3,950)
Total property, plant and equipment, net	671,720	669,476
Gas in underground storage [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	1,768	2,345
Natural gas pipelines [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	421,756	421,644
Processing and treating assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	199,743	195,108
Buildings [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	15,518	15,518
Vehicles [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	3,239	3,138
Land [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	1,534	1,534
General and other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	1,218	1,207
Construction work in progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	$52,106	$32,932

Goodwill_Additional_Informatio

Goodwill - Additional Information (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Goodwill [Line Items]	'	'
Business acquisition goodwill amount	$302,916	$301,852
Gas Transportation and Storage segment [Member]	'	'
Goodwill [Line Items]	'	'
Business acquisition goodwill amount	224,900	'
Processing segment [Member]	'	'
Goodwill [Line Items]	'	'
Business acquisition goodwill amount	$78,000	'

Risk_Management_Additional_Inf

Risk Management - Additional Information (Detail) (USD $)	3 Months Ended	9 Months Ended		3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012
	Significant unobservable inputs (Level 3) [Member]	Significant unobservable inputs (Level 3) [Member]	Commodity [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]
			Bcf			Significant unobservable inputs (Level 3) [Member]	Significant unobservable inputs (Level 3) [Member]
Derivative [Line Items]	'	'	'	'	'	'	'
Recognition of gain or loss on derivatives associated with the ineffectiveness of hedges	'	'	'	$0	$0	'	'
Gain or loss reclassified into earnings as a result of the discontinuance of cash flow hedges	'	'	'	0	0	'	'
Derivative volumes	'	'	0.2	'	'	'	'
Derivative liabilities with a fair value	'	'	'	'	'	'	$257,000

Risk_Management_Schedule_of_Fa

Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Total derivative assets	$24	$224
Total derivative liabilities	5	23
Energy commodity derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Total derivative assets	24	224
Total derivative liabilities	5	23
Energy commodity derivative contracts [Member] | Current assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Total derivative assets	24	224
Energy commodity derivative contracts [Member] | Current liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Total derivative liabilities	$5	$23

Risk_Management_Derivative_Con

Risk Management - Derivative Contracts Included in Combined Statements of Income (Detail) (Energy commodity derivative contracts [Member], USD $)	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012
	Designated as Hedging Instrument [Member]	Designated as Hedging Instrument [Member]	Derivatives not designated as hedging contracts [Member]	Derivatives not designated as hedging contracts [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]
	Derivatives in cash flow hedging relationships [Member]	Derivatives in cash flow hedging relationships [Member]			Designated as Hedging Instrument [Member]	Designated as Hedging Instrument [Member]	Derivatives not designated as hedging contracts [Member]	Derivatives not designated as hedging contracts [Member]
					Derivatives in cash flow hedging relationships [Member]	Derivatives in cash flow hedging relationships [Member]
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'	'	'	'
Amount of gain/(loss) recognized in OCI on derivative (effective portion)	'	'	'	'	($366)	$978	'	'
Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)	'	'	'	'	1,584	3,535	'	'
Amount of gain/(loss) recognized in income on derivative	'	'	($91)	($375)	'	'	'	'
Location of gain/(loss) reclassified from AOCI into income (effective portion)	'Natural gas sales	'Natural gas sales	'	'	'Natural gas sales	'Natural gas sales	'	'
Location of gain/(loss) recognized in income on derivative	'	'	'Natural gas sales	'Natural gas sales	'	'	'Natural gas sales	'Natural gas sales

Risk_Management_Maximum_Potent

Risk Management - Maximum Potential Exposure to Credit Losses on TEP's Derivative Contracts (Detail) (USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Gross exposure	$24
Netting agreement impact	-5
Cash collateral held	'
Net exposure	$19

Risk_Management_Schedule_of_En

Risk Management - Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$24	$224
Energy commodity derivative contracts	5	23
Energy commodity derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	24	224
Energy commodity derivative contracts	5	23
Quoted prices in active markets for identical assets (Level 1) [Member] | Energy commodity derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	'	'
Energy commodity derivative contracts	'	'
Significant other observable inputs (Level 2) [Member] | Energy commodity derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	24	224
Energy commodity derivative contracts	5	23
Significant unobservable inputs (Level 3) [Member] | Energy commodity derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	'	'
Energy commodity derivative contracts	'	'

Risk_Management_Schedule_of_En1

Risk Management - Schedule of Energy Commodity Derivative Contracts (Detail) (Significant unobservable inputs (Level 3) [Member], USD $)	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012
			TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'
Beginning of period	'	'	'	($352)
Total gains or (losses) Included in other comprehensive income	'	'	'	-62
Settlements	'	'	'	157
Transfers out of Level 3	'	'	'	257
End of period	'	'	'	'
The amount of total gains or losses for the period included in earnings attributable to the change in unrealized gains or losses relating to assets held at the reporting date	'	'	'	'

Longterm_Debt_Additional_Infor

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

9 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

Sep. 30, 2013

17-May-13

Sep. 30, 2013

Sep. 30, 2013

17-May-13

Sep. 30, 2013

17-May-13

17-May-13

17-May-13

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

17-May-13

Sep. 30, 2013

Sep. 30, 2013

17-May-13

17-May-13

Mar. 31, 2013

17-May-13

Apr. 30, 2013

Nov. 13, 2012

Apr. 30, 2013

Minimum [Member]

Maximum [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Swingline Loan [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Eurodollar [Member]

Eurodollar [Member]

Eurodollar [Member]

Eurodollar [Member]

Eurodollar [Member]

Alternate Base Rate [Member]

Us Federal Fund [Member]

Base Rate [Member]

Base Rate [Member]

Base Rate [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

TD [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Barclays Bank [Member]

Senior Revolving Credit Facility [Member]

Minimum [Member]

Maximum [Member]

Revolving Credit Facility [Member]

Swingline Loan [Member]

Revolving Credit Facility [Member]

Minimum [Member]

Maximum [Member]

Swingline Loan [Member]

Limited Partners [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Eurodollar [Member]

Alternate Base Rate [Member]

Limited Partners [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing interest rate margin

'

'

'

'

'

'

'

'

'

'

4.00%

2.00%

3.00%

1.00%

2.00%

3.00%

0.50%

1.00%

2.00%

1.00%

'

'

'

'

'

4.00%

'

'

'

3.00%

Minimum variable interest rate

1.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term loan maturity date

13-Nov-18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business combination, long-term debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$400,000,000

$400,000,000

$400,000,000

'

Maximum borrowing capacity under new credit agreement

'

500,000,000

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

17,526,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility maturity date

'

'

'

'

'

'

17-May-18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Borrowing Capacity

226,000,000

'

'

'

231,000,000

226,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayment of debt assumed from TD

'

'

'

'

104,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of additional shares by underwriter

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31,200,000

'

31,200,000

'

'

'

'

'

Reimbursement for a portion of capital expenditures made by related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

85,500,000

85,500,000

'

85,500,000

'

'

'

'

'

'

Increase in revolving borrowings

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Borrowing Capacity

'

'

'

'

'

'

'

40,000,000

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt issued

'

'

'

'

'

'

'

'

'

$700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated leverage ratio

'

'

4.75

5.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated interest coverage ratio

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility commitment fee

0.38%

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average interest rate on outstanding borrowings

2.21%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Longterm_Debt_Summary_of_Long_

Long-term Debt - Summary of Long Term Debt (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Disclosure [Abstract]	'	'
Borrowings under revolving credit facility	$226,000	'
Term loan due 2018 (allocated from TD)	'	400,000
Unamortized discount	'	-5,509
Total principal	226,000	394,491
Current maturities	'	-4,000
Total long-term debt	$226,000	$390,491

Longterm_Debt_Carrying_Amount_

Long-term Debt - Carrying Amount and Fair Value of TEP's Long-term Debt (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Fair Value	$226,000	$404,000
Carrying Amount	226,000	394,491
Quoted prices in active markets for identical assets (Level 1) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	'	'
Significant other observable inputs (Level 2) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	226,000	404,000
Significant unobservable inputs (Level 3) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	'	'

Partnership_Equity_and_Distrib1

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

1 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 30, 2013

17-May-13

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

17-May-13

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Oct. 07, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

TD [Member]

TD [Member]

TD [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Thereafter [Member]

Subsequent Event [Member]

Distribution One [Member]

Distribution Two [Member]

Distribution Three [Member]

Minimum Quarterly Distribution [Member]

First Target Distribution [Member]

Second Target Distribution [Member]

Third Target Distribution [Member]

Limited Partners [Member]

TD [Member]

Limited Partners' Capital Account [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units issued to TD in exchange for the contribution of TIGT and TMID

'

9,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subordinated unit

'

16,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution declaration date

'

'

7-Oct-13

18-Jul-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution payable date

'

'

13-Nov-13

13-Aug-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution date of record

'

'

1-Nov-13

31-Jul-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution declared per unit

'

'

'

'

'

'

'

'

'

'

'

$0.30

'

'

'

'

'

'

'

'

Cash distribution paid per unit

$0.14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.29

'

'

'

'

General partner units issued to Tallgrass MLP GP, LLC (the "GP")

'

826,531

826,531

'

826,531

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partner interest in TEP as well as IDRs

'

2.00%

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increasing incentive distribution right

'

'

'

'

'

'

'

'

'

'

'

'

13.00%

23.00%

48.00%

'

'

'

'

'

Incentive distribution per unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.30

$0.35

$0.43

'

Percentage of unit holders

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

98.00%

85.00%

75.00%

'

Percentage of general partner

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

2.00%

15.00%

25.00%

'

Distribution from TEP to TD

'

'

'

'

'

'

$0

$118.50

$13.50

$53.50

'

'

'

'

'

'

'

'

'

'

Reimbursement for a portion of capital expenditures made by related party

'

'

'

'

'

85.5

'

85.5

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of additional shares by underwriter

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$31.20

Net_Income_per_Limited_Partner2

Net Income per Limited Partner Unit - Summary of Net Income Per Limited Partner Unit (Detail) (USD $)	3 Months Ended	4 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	16-May-13	Sep. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net Income (Loss)	$7,006	($6,632)	$6,982	$350
General partner interest in net income (loss)	140	-133	6,982	6,849
Net income (loss) available to common and subordinated unitholders	$6,866	($6,499)	'	($6,499)
Basic net loss per common and subordinated unit	$0.17	($0.16)	'	($0.16)
Diluted net loss per common and subordinated unit	$0.17	($0.16)	'	($0.16)
Basic average number of common and subordinated units outstanding	40,500	40,417	'	40,417
Equity Participation Unit equivalent units	363	'	'	'
Diluted average number of common and subordinated units outstanding	40,863	40,417	'	40,417

Net_Income_per_Limited_Partner3

Net Income per Limited Partner Unit - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Number of antidilutive units excluded	1,500,000
Number of dilutive units included	933,000

Reporting_Segments_Additional_

Reporting Segments - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2013
	Segment
Segment Reporting [Abstract]	'
Number of reportable segments	2

Reporting_Segments_Summary_of_

Reporting Segments - Summary of TEP and TEP Pre-Predecessor's Segment Information (Detail) (USD $)

3 Months Ended

4 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Thousands, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2013

16-May-13

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Operating Segments [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Operating Segments [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Gas Transportation and Storage segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Processing segment [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Operating Segments [Member]

Operating Segments [Member]

Inter-Segment [Member]

Inter-Segment [Member]

Net Adjusted EBITDA [Member]

Net Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

External Adjusted EBITDA [Member]

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sales and revenues

$63,259

'

'

$186,919

'

$63,410

$187,440

($151)

($521)

'

'

$26,283

$77,399

$26,434

$77,920

'

($151)

($521)

'

'

'

'

$36,976

$109,520

$36,976

$109,520

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$64,478

$190,526

$64,662

$191,123

($184)

($597)

'

'

$30,907

$90,040

$31,091

$90,637

($184)

($597)

'

'

'

'

$33,571

$100,486

$33,571

$100,486

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjusted EBITDA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-151

-521

13,733

37,043

13,582

36,522

'

'

'

'

'

151

521

3,644

15,713

3,795

16,234

'

'

'

'

'

'

-632

-939

-632

-939

'

'

'

'

'

'

'

'

'

'

'

'

-184

-597

14,677

45,603

14,493

45,006

'

'

'

'

184

597

3,711

15,536

3,895

16,133

'

'

'

'

'

'

'

'

'

'

Reconciliation to Income (Loss) before Income Taxes:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest expense (income), net

1,422

'

'

1,458

'

'

'

'

'

1,422

10,486

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,446

-1,446

'

'

'

'

-1,446

-1,446

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Texas Margin Taxes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

193

'

'

'

'

20

193

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation and amortization expense

7,342

'

'

22,324

'

'

'

'

'

7,342

22,324

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,949

17,776

'

'

'

'

5,949

17,776

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

'

'

'

17,526

'

'

'

'

'

'

17,526

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-cash loss related to derivative instruments

'

'

'

'

'

'

'

'

'

112

183

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-cash compensation expense

'

'

'

948

'

'

'

'

'

863

948

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income before income taxes

7,006

-6,632

6,982

350

'

'

'

'

'

7,006

350

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,865

44,616

'

'

'

'

13,865

44,616

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

Segment assets

$1,026,236

$1,026,236

'

$1,026,236

$1,035,814

'

'

'

'

'

'

'

'

$706,218

$706,218

$741,595

'

'

'

'

'

'

'

'

$312,998

$312,998

$294,219

'

'

'

'

'

'

'

'

$7,020

$7,020

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

Equity_Based_Compensation_Addi

Equity Based Compensation - Additional Information (Detail) (USD $)	1 Months Ended	3 Months Ended	9 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 26, 2013	Sep. 30, 2013	Sep. 30, 2013
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Equity participation units granted	'	'	1,500,000
Share-based compensation expense related to the EPU grants recognized	'	2	2.1
Compensation cost related to nonvested EPUs expected to be recognized	'	19.6	19.6
Weighted average period in which compensation cost related to nonvested EPUs expected to be recognized	'	'	'2 years 10 months 24 days
TEP [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Share-based compensation expense related to the EPU grants recognized	'	0.9	1
Equity Participation Unit [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Equity participation units granted	1,490,000	5,500	1,495,500
Equity Participation Unit [Member] | Maximum [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Equity participation units granted	1,500,000	'	'

Equity_Based_Compensation_Summ

Equity Based Compensation - Summarizes Changes in EPUs Outstanding (Detail) (USD $)	1 Months Ended	3 Months Ended	9 Months Ended
	Jun. 26, 2013	Sep. 30, 2013	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Granted, Shares	'	'	1,500,000
Equity Participation Unit [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Beginning of period, Shares	'	1,490,000	'
Granted, Shares	1,490,000	5,500	1,495,500
Forfeited, Shares	'	-29,500	-29,500
End of period, Shares	'	1,466,000	1,466,000
Beginning of period, Weighted Average Grant Date Fair Value	'	$17.49	'
Granted, Weighted Average Grant Date Fair Value	'	$18.92	$17.49
Forfeited, Weighted Average Grant Date Fair Value	'	($17.49)	($17.49)
End of period, Weighted Average Grant Date Fair Value	'	$17.49	$17.49

Regulatory_Matters_Additional_

Regulatory Matters - Additional Information (Detail) (Natural gas pipelines [Member])	Aug. 06, 2012
	Miles
Natural gas pipelines [Member]	'
Rate And Regulatory Matters [Line Items]	'
Gas transmission lines to be sold	432

Legal_and_Environmental_Matter1

Legal and Environmental Matters - Additional Information (Detail) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	30-May-13	Sep. 30, 2012	Dec. 31, 2009	Dec. 31, 2012	Feb. 29, 2012	Mar. 23, 2009	Sep. 21, 2012
			Cornhusker Energy Lexington Plant Explosion [Member]	Tallgrass Midstream LLC [Member]	TEP Pre-Predecessor [Member]	TEP Pre-Predecessor [Member]	TEP Predecessor [Member]	Conoco Philips NGL [Member]	Elkhorn Construction Inc [Member]	Elkhorn Construction Inc [Member]
				Elkhorn Mechanic Lien [Member]				TEP Pre-Predecessor [Member]		TEP Pre-Predecessor [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'	'	'
Aggregate reserves for all claims	'	$100,000	'	'	'	'	'	'	'	'
Amount of damages sought in claim	'	'	3,900,000	'	'	'	'	'	4,900,000	'
Settlement amount awarded	'	'	'	'	'	'	'	'	'	4,700,000
Interest rate on mechanics lien	'	'	'	'	'	'	'	'	'	7.00%
Payment of damages	'	'	'	'	'	'	'	1,100,000	'	5,900,000
Lien claim expense paid	'	'	'	200,000	'	'	'	'	'	'
Amount recognized to settle the issue with the affiliated refinery that received the product from ConocoPhillips	'	'	'	'	'	1,100,000	'	'	'	'
Amount recovered from two parties who delivered the contested product	'	'	'	'	'	'	350,000	'	'	'
Environmental accruals	3,500,000	3,500,000	'	'	'	'	'	'	'	'
Environmental remediation expense per facility (Douglas and Casper Gas Plants)	'	'	'	'	$158,000	'	'	'	'	'

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (Subsequent Event [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Oct. 01, 2013
Subsequent Event [Line Items]	'
Payment from TD for the expected sale of "Pony Express Assets"	$84.90
Revolving Credit Facility [Member]	'
Subsequent Event [Line Items]	'
Amount of borrowings repaid by use of proceeds from sale of assets	$85