Tallgrass Energy Partners 10-Q 7 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	2-May-14	2-May-14	2-May-14
		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	31-Mar-14	'	'	'
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q1	'	'	'
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	'	24,685,140	16,200,000	834,391

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current Assets:	'	'
Accounts receivable, net	$25,663	$27,615
Gas imbalances	2,743	2,598
Inventories	11,352	5,148
Prepayments and other current assets	4,264	16,986
Total Current Assets	44,022	52,347
Property, plant and equipment, net	593,301	594,911
Goodwill	304,474	304,474
Unconsolidated investment	3,031	1,255
Deferred financing costs	4,255	4,512
Deferred charges and other assets	9,994	10,299
Total Assets	959,077	967,798
Current Liabilities:	'	'
Accounts payable	43,021	54,621
Accounts payable to related parties	3,655	7,134
Gas imbalances	9,176	3,142
Derivative liabilities at fair value	535	184
Accrued taxes	5,172	4,427
Accrued other current liabilities	12,073	14,777
Total Current Liabilities	73,632	84,285
Long-term debt	135,000	135,000
Other long-term liabilities and deferred credits	4,510	4,572
Total Long-term Liabilities	139,510	139,572
Commitments and Contingencies (Note 12)	'	'
Partners' Capital:	'	'
General partner (826,531 units issued and outstanding at March 31, 2014 and December 31, 2013)	14,135	14,078
Total Partners' Capital	745,935	743,941
Total Liabilities and Partners' Capital	959,077	967,798
Common unitholders [Member]	'	'
Partners' Capital:	'	'
Partner's capital	457,230	455,197
Subordinated unitholder [Member]	'	'
Partners' Capital:	'	'
Partner's capital	$274,570	$274,666

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical)	Mar. 31, 2014	Dec. 31, 2013
General partner units issued	826,531	826,531
General partner units outstanding	826,531	826,531
Common unitholders [Member]	'	'
Partner's capital units issued	24,300,000	24,300,000
Partner's capital units outstanding	24,300,000	24,300,000
Subordinated unitholder [Member]	'	'
Partner's capital units issued	16,200,000	16,200,000
Partner's capital units outstanding	16,200,000	16,200,000

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Revenues:	'	'
Natural gas liquids sales	$48,907	$33,401
Natural gas sales	2,196	301
Transportation services	27,051	24,337
Processing and other revenues	6,808	2,219
Total Revenues	84,962	60,258
Operating Costs and Expenses:	'	'
Cost of sales and transportation services	50,446	29,470
Operations and maintenance	7,286	6,535
Depreciation and amortization	6,514	7,546
General and administrative	6,201	4,634
Taxes, other than income taxes	1,456	1,777
Total Operating Costs and Expenses	71,903	49,962
Operating Income	13,059	10,296
Other (Expense) Income:	'	'
Interest (expense) income, net	-1,324	-5,564
Equity in earnings of unconsolidated investment	444	'
Other income, net	721	339
Total Other Expense	-159	-5,225
Net Income	12,900	5,071
Total comprehensive income	12,900	5,071
Allocation of income for the three months ended March 31, 2014:	'	'
General partner interest in net income	382	'
Common and subordinated unitholders' interest in net income	12,518	'
Net Income	$12,900	$5,071
Basic net income per common and subordinated unit	$0.31	'
Diluted net income per common and subordinated unit	$0.30	'
Basic average number of common and subordinated units outstanding	40,500	'
Diluted average number of common and subordinated units outstanding	41,272	'

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash Flows from Operating Activities:	'	'
Net Income	$12,900	$5,071
Adjustments to reconcile net income to net cash flows from operating activities:	'	'
Depreciation and amortization	6,843	8,297
Noncash compensation expense	941	'
Noncash change in fair value of derivative financial instruments	351	919
Equity in earnings of unconsolidated investment	-444	'
Distributions from unconsolidated investment	444	'
Changes in components of working capital:	'	'
Accounts receivable and other	2,461	-565
Gas imbalances	628	307
Inventories	-942	-2,181
Accounts payable and accrued liabilities	-9,865	20,066
Other, net	6,290	107
Net Cash Provided by Operating Activities	19,607	32,021
Cash Flows from Investing Activities:	'	'
Capital expenditures	-5,947	-8,943
Net cash paid for purchase and sale of gas in underground storage	-31	'
Unconsolidated investment	-1,841	'
Distributions from unconsolidated investment in excess of cumulative earnings	64	'
Proceeds from disposal of property, plant and equipment (net of removal costs)	29	6
Net Cash Used in Investing Activities	-7,726	-8,937
Cash Flows from Financing Activities:	'	'
Distributions to Member, net	'	-23,084
Distributions to unitholders	-13,082	'
Reimbursement of stock compensation expense from TD	1,201	'
Net Cash Used in Financing Activities	-11,881	-23,084
Net Change in Cash and Cash Equivalents	'	'
Cash and Cash Equivalents, beginning of period	'	'
Cash and Cash Equivalents, end of period	'	'
Supplemental Disclosures:	'	'
Cash payments for interest	1,151	'
Schedule of Noncash Investing and Financing Activities:	'	'
Receivable for unreimbursed stock compensation from TD	$437	'

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL (UNAUDITED) (USD $)	Total	Limited Partners [Member]	Limited Partners [Member]	General Partner [Member]
In Thousands		Common unitholders [Member]	Subordinated unitholder [Member]
Beginning Balance at Dec. 31, 2013	$743,941	$455,197	$274,666	$14,078
Net Income	12,900	7,511	5,007	382
Distributions to unitholders	-13,082	-7,654	-5,103	-325
Noncash compensation expense	2,176	2,176	'	'
Ending Balance at Mar. 31, 2014	$745,935	$457,230	$274,570	$14,135

Description_of_Business

Description of Business	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Description of Business	'
	1	Description of Business
	Tallgrass Energy Partners, LP (“TEP” or the “Partnership”) is a Delaware limited partnership formed in February 2013.
	On May 17, 2013, TEP closed its initial public offering (“IPO”). The 14,600,000 common units held by the public constitute approximately 36% of TEP’s aggregate outstanding common and subordinated units and approximately 35% of TEP’s aggregate outstanding common, subordinated and general partner units at March 31, 2014. TD held 9,700,000 common units and 16,200,000 subordinated units at March 31, 2014 which comprised approximately 64% of TEP’s aggregate outstanding common and subordinated units and approximately 63% of TEP’s aggregate outstanding common, subordinated and general partner units. In addition, as part of the contribution transaction, 826,531 general partner units, representing a 2% general partner interest in TEP at March 31, 2014, and all of the incentive distribution rights (“IDRs”) were issued to Tallgrass MLP GP, LLC (the “general partner”). In connection with the IPO, TEP entered into a revised partnership agreement on May 17, 2013. The amended and restated partnership agreement requires TEP to distribute its available cash on a quarterly basis, subject to certain terms and conditions, beginning with the quarter ending June 30, 2013. For additional information, see Note 8 – Partnership Equity and Distributions.
	The term “Predecessor Entity” refers to Tallgrass Energy Partners Predecessor (“TEP Predecessor”), which is comprised of the businesses described below that were owned by TD, from November 13, 2012 through the completion of the IPO on May 17, 2013.
	The businesses included in the Predecessor Entity consist of:
		•	Tallgrass Interstate Gas Transmission, LLC (“TIGT”), which owns an interstate gas pipeline and storage system that is regulated by the FERC. TIGT currently has approximately 4,645 miles of varying diameter natural gas transmission lines in Colorado, Kansas, Missouri, Nebraska and Wyoming (the “TIGT System”).
		•	Tallgrass Midstream, LLC (“TMID”), which owns and operates one treating and two processing plants in Wyoming.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	2	Summary of Significant Accounting Policies
	Basis of Presentation
	These unaudited condensed consolidated financial statements and related notes for the three months ended March 31, 2014 and 2013 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of generally accepted accounting principles in the United States of America (“GAAP”) for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include disclosures required by GAAP for annual periods. The unaudited condensed consolidated financial statements for the three months ended March 31, 2014 and 2013 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair presentation of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Certain prior period amounts have been reclassified to conform to the current presentation.
	TEP’s financial results for the three months ended March 31, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014. These unaudited condensed consolidated financial statements should be read in conjunction with TEP’s audited consolidated financial statements and notes thereto included in its Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”) filed with the Securities Exchange Commission (the “SEC”) on March 11, 2014.
	The accompanying consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to TEP by TD in connection with the IPO for the periods prior to May 17, 2013, the closing date of TEP’s IPO, 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 consolidated financial statements include the accounts of TEP and its subsidiaries. Significant intra-entity items have been eliminated in the presentation. Net equity distributions of the Predecessor Entity included in the Consolidated Statements of Cash Flows represent transfers of cash as a result of TD’s centralized cash management systems prior to May 17, 2013, under which cash balances were swept daily and recorded as loans from the subsidiaries to TD. These loans were then periodically recorded as equity distributions.
	Use of Estimates
	Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on TEP’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	3	Related Party Transactions
	TEP has no employees. Beginning November 13, 2012, TD provided and charged TEP for all direct and indirect costs of services provided to us or incurred on our behalf including employee labor costs, information technology services, employee health and life benefits, and all other expenses necessary or appropriate to the conduct of our business. TEP recorded these costs on the accrual basis in the period in which TD incurred them. Each of the wholly-owned companies comprising TEP had an agency arrangement with TD under which TD paid costs and expenses incurred by TEP, acted as an agent for TEP, and was reimbursed by TEP for such payments.
	On May 17, 2013, in connection with the closing of TEP’s IPO, TEP and its subsidiaries entered into an Omnibus Agreement with TD and certain of its affiliates (the “Omnibus Agreement”). The Omnibus Agreement provides that, among other things, TEP will reimburse TD and its affiliates for all expenses they incur and payments they make on TEP’s behalf, including the costs of employee and director compensation and benefits as well as the cost of the provision of certain centralized corporate functions performed by TD, including legal, accounting, cash management, insurance administration and claims processing, risk management, health, safety and environmental, information technology and human resources in each case to the extent reasonably allocable to TEP.
	For the calendar year 2014, TEP’s annual cost reimbursements to TD for costs discussed above, are expected to be $19.9 million, inclusive of costs associated with our acquisition of Trailblazer Pipeline Company, LLC (“Trailblazer”) in April 2014, as discussed in Note 14 – Subsequent Events. TEP also pays a quarterly reimbursement to TD for costs associated with being a public company. The quarterly public company reimbursement was $625,000 for the first quarter of 2014 and TEP currently expects it to remain the same for each subsequent quarter in 2014. However, these reimbursement amounts will be periodically reviewed and adjusted as necessary to continue to reflect reasonable allocation of costs to TEP.
	Due to the cash management agreement discussed in Note 2 – Summary of Significant Accounting Policies, intercompany balances at the Predecessor Entity were periodically settled and treated as equity distributions prior to the completion of the IPO on May 17, 2013.
	Totals of transactions with affiliated companies are as follows:
			Three Months		Three Months
			Ended		Ended
			March 31, 2014		March 31, 2013
			(in thousands)
	Charges to TEP: (1)
	Property, plant and equipment, net		$	5,316	$	4,709
	Other deferred charges		$	582	$	1,038
	Operation and maintenance		$	3,840	$	3,586
	General and administrative (2)		$	4,224	$	4,634
	(1)	Charges to TEP include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three months ended March 31, 2014 and 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in allocated amounts for general and administrative costs.
	Details of balances with affiliates included in “Accounts receivable” and “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
			March 31, 2014		December 31, 2013
			(in thousands)
	Accounts receivable from affiliated companies:
	Rockies Express Pipeline LLC		$	29	$	—
	Total accounts receivable from affiliated companies		$	29	$	—
	Payables to affiliated companies:
	Accounts payable to Tallgrass Operations, LLC		$	3,655	$	7,106
	Accounts payable to Rockies Express Pipeline LLC			—		28
	Total payables to affiliated companies		$	3,655	$	7,134
	Balances of gas imbalances with affiliated shippers are as follows:
			March 31, 2014		December 31, 2013
			(in thousands)
	Affiliate gas balance receivables		$	—	$	7
	Affiliate gas balance payables		$	1,633	$	116
	Pursuant to the terms of a Purchase and Sale Agreement dated August 1, 2012, TD, on behalf of its wholly-owned subsidiary, Tallgrass Pony Express Pipeline, LLC (“PXP”), is reimbursing TIGT for all costs TIGT incurs with respect to the Pony Express Abandonment, as defined in Note 11 – 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 (the “Replacement Gas Facilities”). The Replacement Gas Facilities are required as part of the Pony Express Abandonment in order for TIGT to continue service to existing customers after having sold approximately 430 miles of natural gas pipeline, and associated rights of way and certain other equipment, to PXP in 2013. For more information, see Note 5 – Property, Plant and Equipment and Note 11 – Regulatory Matters.
	TIGT’s expenditures for the Replacement Gas Facilities are being captured in “Prepayments and other current assets” in the Condensed Consolidated Balance Sheets as they are incurred and interest is accrued until reimbursement takes place (which is usually monthly). At March 31, 2014, TEP had $4.0 million in “Prepayments and other current assets” related to this project due to $26.2 million of expenditures during the three months ended March 31, 2014, which were partially offset by reimbursements of $22.2 million that were cash settled by TD. At December 31, 2013, TEP had $17.0 million in “Prepayments and other current assets” related to this project that were cash settled by TD in the first quarter of 2014.

Inventory

Inventory	3 Months Ended
	Mar. 31, 2014
Inventory Disclosure [Abstract]	'
Inventory	'
	4	Inventory
	The components of inventory at March 31, 2014 and December 31, 2013 consisted of the following:
			March 31, 2014		December 31, 2013
			(in thousands)
	Materials and supplies		$	1,730	$	1,736
	Natural gas liquids			1,164		1,009
	Gas in underground storage			8,458		2,403
	Total inventory		$	11,352	$	5,148

Property_Plant_and_Equipment

Property, Plant and Equipment	3 Months Ended
	Mar. 31, 2014
Property Plant And Equipment [Abstract]	'
Property, Plant and Equipment	'
	5	Property, Plant and Equipment
	A summary of net property, plant and equipment by classification is as follows:
			March 31, 2014			December 31, 2013
			(in thousands)
	Natural gas pipelines		$	348,481		$	339,430
	Processing and treating assets			234,541			209,329
	General and other			25,202			24,859
	Construction work in progress			7,984			39,369
	Accumulated depreciation and amortization			(22,907	)		(18,076	)
	Total property, plant and equipment, net		$	593,301		$	594,911

Risk_Management

Risk Management

3 Months Ended

Mar. 31, 2014

Derivative Instruments And Hedging Activities Disclosure [Abstract]

'

Risk Management

'

6

Risk Management

TEP occasionally enters into derivative contracts with third parties for the purpose of hedging exposures that accompany its normal business activities. TEP’s normal business activities expose it to risks associated with changes in the market price of commodities, including, among others, natural gas. Specifically, the risks associated with changes in the market price of natural gas, include, among others (i) pre-existing or anticipated physical natural gas sales, (ii) natural gas purchases and (iii) natural gas system use and storage. TEP has elected not to apply hedge accounting and changes in the fair value of all derivative contracts are recorded in earnings in the period in which the change occurs.

Fair Value of Derivative Contracts

The following table summarizes the fair values of TEP’s derivative contracts included in the accompanying Condensed Consolidated Balance Sheets:

Balance Sheet

March 31, 2014

December 31, 2013

Location

(in thousands)

Energy commodity derivative contracts

Current liabilities

$

535

$

184

As of March 31, 2014, the fair value shown for commodity contracts was comprised of derivative volumes totaling 0.9 Bcf of fixed-price swaps. TEP did not recognize any derivative contracts in asset positions as of March 31, 2014 or December 31, 2013.

Effect of Derivative Contracts on the Income Statement

The following table summarizes the impact of derivative contracts included in the accompanying Condensed Consolidated Statements of Income and Comprehensive Income for the three months ended March 31, 2014 and 2013:

Amount of loss recognized in

income on derivatives

Location of

Three Months

Three Months

loss recognized

Ended

Ended

in income on

March 31,  2014

March 31,  2013

derivatives

(in thousands)

(in thousands)

Derivatives not designated as hedging contracts:

Energy commodity derivative contracts

Natural gas sales

$

(351

)

$

(919

)

Credit Risk

TEP has counterparty credit risk as a result of its 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 currently anticipate a material adverse effect on TEP’s financial position, results of operations, or cash flows as a result of counterparty performance.

TEP’s over-the-counter swaps are entered into with counterparties outside central trading organizations such as a futures, options or stock exchange. These contracts are with 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. As of March 31, 2014, the fair value of TEP’s derivative contracts was a liability, resulting in no credit exposure from TEP’s counterparty as of that date.

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

Fair Value

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

OTC derivatives are valued using models utilizing a variety of inputs including contractual terms, commodity and interest rate curves and measures of volatility. The selection of a particular model and particular inputs to value an OTC derivative contract depends upon the contractual terms of the instrument as well as the availability of pricing information in the market. TEP uses similar models to value similar instruments. For OTC derivative contracts that trade in liquid markets, such as generic forwards and swaps, model inputs can generally be verified and model selection does not involve significant management judgment. Such contracts are typically classified within Level 2 of the fair value hierarchy.

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

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

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

Liability fair value measurements using

Total

Quoted prices in

Significant

Significant

active markets

other observable

unobservable

for identical

inputs

inputs

assets

(Level 2)

(Level 3)

(Level 1)

(in thousands)

TEP as of March 31, 2014

Energy commodity derivative contracts

$

535

$

—

$

535

$

—

TEP as of December 31, 2013

Energy commodity derivative contracts

$

184

$

—

$

184

$

—

TEP did not recognize any derivative contracts in asset positions as of March 31, 2014 or December 31, 2013.

Longterm_Debt

Long-term Debt

3 Months Ended

Mar. 31, 2014

Debt Disclosure [Abstract]

'

Long-term Debt

'

7

Long-term Debt

Revolving Credit Facility

TEP has a $500 million senior secured revolving credit facility with Barclays Bank PLC, as administrative agent, and a syndicate of lenders which will mature on May 17, 2018. As of March 31, 2014 and December 31, 2013, TEP had outstanding borrowings of $135.0 million, had issued letters of credit totaling $0.7 million and had available borrowing capacity under the revolving credit facility of $364.3 million.

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, TEP is required to maintain a consolidated leverage ratio of not more than 4.75 to 1.00 (which will be increased to 5.25 to 1.00 for certain measurement periods following the consummation of certain acquisitions) and a consolidated interest coverage ratio of not less than 2.50 to 1.00. As of March 31, 2014, TEP is in compliance with the covenants required under the revolving credit facility.

The unused portion of the credit facility is subject to a commitment fee, which was initially 0.375%, and after September 30, 2013, is either 0.375% or 0.500%, based on TEP’s total leverage ratio. As of March 31, 2014, the weighted average interest rate on outstanding borrowings was 2.15%.

Long-term Debt Allocated from TD

On November 13, 2012, TD entered into a credit agreement with a syndicate of lenders which included a term loan, a delayed draw term loan and a revolving credit facility. Prior to May 17, 2013, the long-term debt held by TD was guaranteed by TIGT and TMID, and $400 million of that debt was expected to be assumed by TEP in connection with the IPO. As such, $400 million of the term loan, along with the corresponding discount and deferred financing costs, was allocated to TEP as of November 13, 2012. The term loan is an obligation of TD and prior to May 17, 2013, was guaranteed by TIGT and TMID.

Upon the closing of the IPO on May 17, 2013, TEP legally assumed the previously allocated $400 million portion of the TD term loan and used a portion of the IPO proceeds, along with borrowings under TEP’s $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 year ended December 31, 2013 associated with the portion of deferred financing costs and unamortized discount on the amount of the TD term loan that was allocated to TEP.

Fair Value

The following table sets forth the carrying amount and fair value of TEP’s long-term debt, which is not measured at fair value in the Condensed Consolidated Balance Sheets as of March 31, 2014 and December 31, 2013, but for which fair value is disclosed:

Fair Value

Quoted prices

Significant

Significant

Total

Carrying

in active markets

other observable

unobservable

Amount

for identical assets

inputs

inputs

(Level 1)

(Level 2)

(Level 3)

(in thousands)

31-Mar-14

$

—

$

135,000

$

—

$

135,000

$

135,000

31-Dec-13

$

—

$

135,000

$

—

$

135,000

$

135,000

The long-term debt borrowed under the revolving credit facility is carried at amortized cost. As of March 31, 2014 and December 31, 2013, the fair value approximates the carrying amount for the borrowings under the revolving credit facility using a discounted cash flow analysis. TEP is not aware of any factors that would significantly affect the estimated fair value subsequent to March 31, 2014.

Partnership_Equity_and_Distrib

Partnership Equity and Distributions

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

'

Partnership Equity and Distributions

'

8

Partnership Equity and Distributions

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

The following table shows the distributions for the year ended 2013 and three months ended March 31, 2014:

Distributions

LimitedPartners

General Partner

Distributions

Common and

per Limited

Three Months Ended

Date Paid

Subordinated

Incentive

2%

Total

Partner Unit

(in thousands, except per unit amounts)

March 31, 2014

May 14, 2014(2)

$

13,288

$

126

$

274

$

13,688

$

0.325

December 31, 2013

February 12, 2014

12,757

63

262

13,082

0.315

September 30, 2013

November 13, 2013

12,049

—

245

12,294

0.2975

June 30, 2013

13-Aug-13

5,759

—

118

5,877

0.1422

(1)

(1)

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

(2)

The distribution declared on April 1, 2014 for the first quarter of 2014 is expected to be paid May 14, 2014 subsequent to the date of this Quarterly Report to 40,885,140 common unitholders of record at the close of business on April 30, 2014.

Subordinated Units

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

Incentive Distribution Rights

The general partner owns a 2% general partner interest in TEP which, as of March 31, 2014, was represented by 826,531 general partner units. As discussed in Note 14 – Subsequent Events, in April 2014, in connection with TEP’s acquisition of Trailblazer, the general partner contributed capital in exchange for the issuance of an additional 7,860 general partner units in order to continue to maintain its 2% general partner interest. The general partner also owns all of the IDRs. IDRs represent the right to receive an increasing percentage (13%, 23% and 48%) of quarterly distributions of available cash from operating surplus after the MQD and the target distribution levels have been achieved. The general partner may transfer these rights separately from its general partner interest, subject to restrictions in TEP’s partnership agreement. Under TEP’s partnership agreement, the general partner may at any time contribute additional capital to TEP in order to maintain its 2% general partner interest.

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

If for any quarter:

•

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

•

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

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

•

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

•

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

•

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

•

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

Definition of Available Cash

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

•

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

•

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

•

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

•

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

•

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

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 3 – Related Party Transactions, was recognized as equity distributions during that time period. Net distributions from TEP to TD for the three months ended March 31, 2013 were approximately $23.1 million. Excluding the cash distributions paid to TD as a common and subordinated unitholder, as discussed above, there were no net distributions from TEP to TD for the quarter ended March 31, 2014.

Net_Income_per_Limited_Partner

Net Income per Limited Partner Unit	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Net Income per Limited Partner Unit	'
	9	Net Income per Limited Partner Unit
	The Partnership’s net income is allocated to the general partner and the limited partners, including the holders of the subordinated units, in accordance with their respective ownership percentages, after giving effect to incentive distributions paid to the general partner. Basic and diluted net income per limited partner unit is calculated by dividing limited partners’ interest in net income, less general partner incentive distributions, by the weighted average number of outstanding limited partner units during the period.
	TEP computes earnings per unit using the two-class method for Master Limited Partnerships as prescribed in the FASB guidance. The two-class method requires that securities that meet the definition of a participating security be considered for inclusion in the computation of basic earnings per unit. Under the two-class method, earnings per unit is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.
	TEP calculates net income available to limited partners based on the distributions pertaining to the current period’s net income. After adjusting for the appropriate period’s distributions, the remaining undistributed earnings or excess distributions over earnings, if any, are allocated to the general partner and limited partners in accordance with the contractual terms of the partnership agreement and as further prescribed in the FASB guidance under the two-class method.
	The two-class method does not impact TEP’s overall net income or other financial results; however, in periods in which aggregate net income exceeds its aggregate distributions for such period, it will have the impact of reducing net income per limited partner unit. This result occurs as a larger portion of TEP’s aggregate earnings, as if distributed, is allocated to the incentive distribution rights of the general partner, even though TEP makes distributions on the basis of available cash and not earnings. In periods in which TEP’s aggregate net income does not exceed its aggregate distributions for such period, the two-class method does not have any impact on our calculation of earnings per limited partner unit.
	Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted earnings per unit reflects the potential dilution of common equivalent units that could occur if equity participation units are converted into common units.
	As the IPO was completed on May 17, 2013, no income from the period from January 1, 2013 to May 16, 2013 is allocated to the limited partner units that were issued on May 17, 2013 and all income for such period was allocated to the general partner. Net income per limited partner unit is only calculated for the three months ended March 31, 2014 as no units were outstanding during the same period in 2013.
	The following table illustrates the Partnership’s calculation of net income per common and subordinated unit for the three months ended March 31, 2014:
			Three Months
			Ended
			March 31, 2014
			(in thousands, except
			per unit amounts)
	Net Income		$	12,900
	General partner interest in net income			382
	Net income available to common and subordinated unitholders		$	12,518
	Basic net income per common and subordinated unit		$	0.31
	Diluted net income per common and subordinated unit		$	0.3
	Basic average number of common and subordinated units outstanding			40,500
	Equity Participation Unit equivalent units			772
	Diluted average number of common and subordinated units outstanding			41,272

EquityBased_Compensation

Equity-Based Compensation	3 Months Ended
	Mar. 31, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Equity-Based Compensation	'
	10	Equity-Based Compensation
	Long-term Incentive Plan
	Effective May 13, 2013, the general partner adopted a Long-term Incentive Plan (“LTIP”) pursuant to which awards in the form of unrestricted units, restricted units, equity participation units, options, unit appreciation rights or distribution equivalent rights may be granted to employees, consultants, and directors of the general partner and its affiliates who perform services for or on behalf of TEP or its affiliates, including TD. Vesting and forfeiture requirements are at the discretion of the board of directors of the general partner at the time of the grant.
	The LTIP limits the number of units that may be delivered pursuant to vested awards to 10,000,000 common units. Common units cancelled, forfeited or withheld to satisfy exercise prices or tax withholding obligations will be available for delivery pursuant to other awards. The plan is administered by the board of directors of TEP’s general partner or a committee thereof, which is referred to as the plan administrator.
	The plan administrator may terminate or amend the LTIP at any time with respect to any units for which a grant has not yet been made. The plan administrator also has the right to alter or amend the LTIP or any part of the plan from time to time, including increasing the number of units that may be granted subject to the requirements of the exchange upon which the common units are listed at that time. However, no change in any outstanding grant may be made that would materially reduce the rights or benefits of the participant without the consent of the participant. The LTIP will expire on the earliest of (i) the date common units are no longer available under the plan for grants, (ii) termination of the plan by the plan administrator or (iii) May 13, 2023.
	Equity Participation Units
	On June 26, 2013, TEP’s general partner approved the grant of up to 1.5 million equity participation units (“EPUs”) for issuance to employees and 177,500 EPUs to Section 16 officers under the LTIP. Effective the same date, an aggregate of 1.49 million EPUs were granted to employees and Section 16 officers of the general partner and its affiliates. Vesting of the EPUs granted to employees is contingent upon TD’s Pony Express Pipeline, which upon completion will consist of an approximately 690-mile oil pipeline connecting the Bakken Shale to Cushing, Oklahoma, being placed into service (the “Pony Express Project”) and will occur in two parts, with one-third vesting on the later of the Pony Express Project in-service date or May 13, 2015, and the remaining two-thirds vesting on the later of the Pony Express Project in-service date or May 13, 2017. If the Pony Express Project has not been placed in service by May 13, 2018, the EPUs will expire and no vesting of the EPUs will occur.
	The EPU grants under the LTIP plan are measured at their grant date fair value. The EPUs granted are non-participating with respect to distributions, therefore the grant date fair value is discounted from the grant date fair value of TEP’s common units for the present value of the expected future distributions during the vesting period. Total equity-based compensation cost related to the EPU grants of approximately $2.2 million was recognized for the quarter ended March 31, 2014. Of the total compensation cost, $0.9 million was recognized as compensation expense at TEP for the quarter ended March 31, 2014 and the remainder was allocated to TD. As of March 31, 2014, $17.1 million of total compensation cost related to non-vested EPUs is expected to be recognized over a weighted average period of 2.5 years, a portion of which will be charged to TD.
	The following table summarizes the changes in the EPUs outstanding for the three months ended March 31, 2014:
			Three Months Ended March 31, 2014
			Shares			Weighted Average
						Grant Date Fair Value
	Beginning of period		$	1,474,250		$	17.54
	Granted			31,500			23.68
	Forfeited			(19,000	)		(17.49	)
	End of period		$	1,486,750		$	17.67

Regulatory_Matters

Regulatory Matters	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Regulatory Matters	'
	11	Regulatory Matters
	TIGT
	Pony Express Abandonment – FERC Docket CP12-495
	On August 6, 2012, TIGT filed an application to: (1) abandon for FERC purposes the Pony Express Assets, and the natural gas service therefrom, by transferring those assets to PXP, which will convert the Pony Express Assets into crude oil pipeline facilities; and (2) construct and operate the Replacement Gas Facilities in order to continue service to existing natural gas firm transportation customers following the proposed conversion. This project is referred to as the “Pony Express Abandonment.” The FERC abandonment does not constitute an abandonment for accounting purposes. Pursuant to the terms of the Purchase and Sale Agreement filed with the FERC and cited by the FERC in approving the Pony Express Abandonment, PXP is required to reimburse TIGT for the net book value of the Pony Express Assets plus other TIGT incurred costs required to construct the Replacement Gas Facilities and to arrange substitute gas transportation services to certain TIGT shippers.
	The Pony Express Abandonment and completion of the Pony Express Project by PXP will re-deploy existing pipeline assets to meet the growing market need to transport oil supplies from the Bakken Shale while at the same time continuing to operate TIGT’s natural gas transportation facilities to meet all current and expected needs of its natural gas customers. By a FERC order issued September 12, 2013, TIGT was granted authorization to abandon the Pony Express Assets and construct the Replacement Gas Facilities. On October 7, 2013 TIGT commenced the mobilization of personnel and equipment for the construction of the Replacement Gas Facilities necessary to complete the Pony Express Abandonment to continue service to existing TIGT customers. In December 2013, TIGT removed the Pony Express Assets from gas service and sold those assets to PXP. Additional phases of the Pony Express Abandonment are expected to be completed during the third quarter of 2014. TIGT’s estimated commencement date to start commercial service of the Replacement Gas Facilities is projected to be in the second quarter of 2014.

Legal_and_Environmental_Matter

Legal and Environmental Matters	3 Months Ended
	Mar. 31, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Legal and Environmental Matters	'
	12	Legal and Environmental Matters
	Legal
	In addition to the matters discussed below, TEP is a defendant in various lawsuits arising from the day-to-day operations of 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 has evaluated claims in accordance with the accounting guidance for contingencies that it deems both probable and reasonably estimable and, accordingly, has aggregate reserves for all claims of approximately $0.6 million and $0.3 million as of March 31, 2014 and December 31, 2013, respectively.
	TIGT
	System Failures
	On May 4, 2013 and on June 13, 2013, a failure occurred on two separate segments of the TIGT pipeline system; one in Kimball County, Nebraska and one in Goshen County, Wyoming. Both failures resulted in the release of natural gas. Both lines were promptly brought back into service and neither failure caused any known injuries, fatalities, fires or evacuations. The costs to repair or replace the damaged section in Kimball County, Nebraska were not material. In February 2014, TEP communicated to PHMSA that TEP’s investigation of the pipeline involved in the Kimball County failure is complete and TEP intends to restore pressure to full maximum allowable operating pressure. TEP is currently scheduled to start hydrostatic testing the pipeline related to the Goshen County failure in the third quarter of 2014 as required by the Corrective Action Order received from PHMSA. TEP expects the cost of remaining remediation activities related to the Goshen County failure to approximate $0.5 million.
	Environmental
	TEP is subject to a variety of federal, state and local laws that regulate permitted activities relating to air and water quality, waste disposal, and other environmental matters. TEP believes that compliance with these laws will not have a material adverse impact on its business, cash flows, financial position or results of operations. However, there can be no assurances that future events, such as changes in existing laws, the promulgation of new laws, or the development of new facts or conditions will not cause TEP to incur significant costs. TEP has environmental accruals of $4.9 million and $5.0 million at March 31, 2014 and December 31, 2013, respectively.
	TMID
	Casper Plant, U.S. EPA Notice of Violation
	In August 2011, the U.S. EPA and the WDEQ conducted an inspection of the Leak Detection and Repair (“LDAR”) Program at the Casper Gas Plant in Wyoming. In September 2011, TMID received a letter from the U.S. EPA alleging violations of the Standards of Performance of Equipment Leaks for Onshore Natural Gas Processing Plant requirements under the Clean Air Act. 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.

Reporting_Segments

Reporting Segments	3 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Reporting Segments	'
	13	Reporting Segments
	TEP’s operations are located in the United States and are organized into two reporting segments: (1) Gas Transportation and Storage, and (2) Processing.
	Gas Transportation and Storage
	The Gas Transportation and Storage segment is engaged in ownership and operation of FERC-regulated interstate natural gas pipelines and integrated natural gas storage facilities that provide services to on-system customers (such as third-party LDCs), industrial users and other shippers.
	Processing
	The Processing segment is engaged in ownership and operation of natural gas processing, treating and fractionation facilities that produce NGLs and residue gas that is sold in local wholesale markets or delivered into pipelines for transportation to additional end markets, as well as water transportation services provided to producers.
	Corporate and Other
	Corporate and Other includes corporate overhead costs incurred subsequent to the IPO on May 17, 2013 that are not directly associated with the operations of TEP’s reportable segments, such as interest and fees associated with TEP’s revolving credit facility, public company costs reimbursed to TD, and equity-based compensation expense.
	These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for their respective operations.
	Beginning in the second quarter of 2013, TEP considers Adjusted EBITDA as its primary segment performance measure as TEP believes 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 excluding the impact of interest, income taxes, depreciation and amortization, non-cash income or loss related to derivative instruments, non-cash long-term compensation expense, impairment losses, gains or losses on asset disposals, gains or losses on the repurchase, redemption or early retirement of debt, and earnings from unconsolidated investments, but including the impact of distributions from unconsolidated investments.
	The following tables set forth TEP’s segment information for the periods indicated:
			Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
			Total			Inter-		External			Total		Inter-			External
			Revenue			Segment		Revenue			Revenue		Segment			Revenue
						(in thousands)							(in thousands)
	Gas transportation and storage		$	28,559		$	—	$	28,559		$	23,597	$	(171	)	$	23,426
	Processing			56,403			—		56,403			36,832		—			36,832
	Corporate and other			—			—		—			—		—			—
	Total revenue		$	84,962		$	—	$	84,962		$	60,429	$	(171	)	$	60,258
			Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
			Total					External			Total					External
			Adjusted			Inter-		Adjusted			Adjusted		Inter-			Adjusted
			EBITDA			Segment		EBITDA			EBITDA		Segment			EBITDA
						(in thousands)							(in thousands)
	Gas transportation and storage		$	13,123		$	—	$	13,123		$	12,266	$	(171	)	$	12,095
	Processing			9,596			—		9,596			6,834		171			7,005
	Corporate and other			(625	)		—		(625	)		—		—			—
	Reconciliation to Net Income:
	Interest expense (income), net								1,324								5,564
	Depreciation and amortization expense								6,514								7,546
	Non-cash loss (gain) related to derivative instruments								351								919
	Non-cash compensation expense								941								—
	Distributions from unconsolidated investment								508								—
	Equity in earnings of unconsolidated investment								(444	)							—
	Net Income							$	12,900							$	5,071
			Total Assets
			March 31, 2014			December 31, 2013
			(in thousands)
	Gas transportation and storage		$	627,894		$	636,686
	Processing			326,886			326,599
	Corporate and other			4,297			4,513
	Total assets		$	959,077		$	967,798

Subsequent_Events

Subsequent Events	3 Months Ended
	Mar. 31, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	14	Subsequent Events
	On April 1, 2014, TEP closed the acquisition of Trailblazer from a wholly owned subsidiary of TD for total consideration valued at approximately $164 million, consisting of $150 million in cash and the issuance of 385,140 common units (valued at approximately $14 million based on the March 31, 2014 closing price of TEP’s common units). On that same date, the general partner contributed additional capital in the amount of approximately $263,000 in exchange for the issuance of 7,860 general partner units in order to maintain its 2% general partner interest. The acquisition of Trailblazer represents a change in reporting entity and a transaction between entities under common control.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	These unaudited condensed consolidated financial statements and related notes for the three months ended March 31, 2014 and 2013 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board’s Accounting Standards Codification, the single source of generally accepted accounting principles in the United States of America (“GAAP”) for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include disclosures required by GAAP for annual periods. The unaudited condensed consolidated financial statements for the three months ended March 31, 2014 and 2013 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair presentation of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Certain prior period amounts have been reclassified to conform to the current presentation.
	TEP’s financial results for the three months ended March 31, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014. These unaudited condensed consolidated financial statements should be read in conjunction with TEP’s audited consolidated financial statements and notes thereto included in its Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”) filed with the Securities Exchange Commission (the “SEC”) on March 11, 2014.
	The accompanying consolidated financial statements of TEP include historical cost-basis accounts of the assets of TEP Predecessor, contributed to TEP by TD in connection with the IPO for the periods prior to May 17, 2013, the closing date of TEP’s IPO, 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 consolidated financial statements include the accounts of TEP and its subsidiaries. Significant intra-entity items have been eliminated in the presentation. Net equity distributions of the Predecessor Entity included in the Consolidated Statements of Cash Flows represent transfers of cash as a result of TD’s centralized cash management systems prior to May 17, 2013, under which cash balances were swept daily and recorded as loans from the subsidiaries to TD. These loans were then periodically recorded as equity distributions.
Use of Estimates	'
	Use of Estimates
	Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on TEP’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Schedule of Transactions with Affiliated Companies	'
	Totals of transactions with affiliated companies are as follows:
			Three Months		Three Months
			Ended		Ended
			March 31, 2014		March 31, 2013
			(in thousands)
	Charges to TEP: (1)
	Property, plant and equipment, net		$	5,316	$	4,709
	Other deferred charges		$	582	$	1,038
	Operation and maintenance		$	3,840	$	3,586
	General and administrative (2)		$	4,224	$	4,634
	(1)	Charges to TEP include directly charged wages and salaries, other compensation and benefits, and shared services.
	(2)	During the three months ended March 31, 2014 and 2013, TEP reimbursed TD for general and administrative expenses as discussed above, resulting in allocated amounts for general and administrative costs.
Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets	'
	Details of balances with affiliates included in “Accounts receivable” and “Accounts payable” in the Condensed Consolidated Balance Sheets are as follows:
			March 31, 2014		December 31, 2013
			(in thousands)
	Accounts receivable from affiliated companies:
	Rockies Express Pipeline LLC		$	29	$	—
	Total accounts receivable from affiliated companies		$	29	$	—
	Payables to affiliated companies:
	Accounts payable to Tallgrass Operations, LLC		$	3,655	$	7,106
	Accounts payable to Rockies Express Pipeline LLC			—		28
	Total payables to affiliated companies		$	3,655	$	7,134
Schedule of Balances of Gas Imbalance with Affiliated Shippers	'
	Balances of gas imbalances with affiliated shippers are as follows:
			March 31, 2014		December 31, 2013
			(in thousands)
	Affiliate gas balance receivables		$	—	$	7
	Affiliate gas balance payables		$	1,633	$	116

Inventory_Tables

Inventory (Tables)	3 Months Ended
	Mar. 31, 2014
Inventory Disclosure [Abstract]	'
Schedule of Components of Inventory	'
	The components of inventory at March 31, 2014 and December 31, 2013 consisted of the following:
		March 31, 2014		December 31, 2013
		(in thousands)
	Materials and supplies	$	1,730	$	1,736
	Natural gas liquids		1,164		1,009
	Gas in underground storage		8,458		2,403
	Total inventory	$	11,352	$	5,148

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2014
Property Plant And Equipment [Abstract]	'
Components of Property Plant and Equipment	'
	A summary of net property, plant and equipment by classification is as follows:
		March 31, 2014			December 31, 2013
		(in thousands)
	Natural gas pipelines	$	348,481		$	339,430
	Processing and treating assets		234,541			209,329
	General and other		25,202			24,859
	Construction work in progress		7,984			39,369
	Accumulated depreciation and amortization		(22,907	)		(18,076	)
	Total property, plant and equipment, net	$	593,301		$	594,911

Risk_Management_Tables

Risk Management (Tables)

3 Months Ended

Mar. 31, 2014

Derivative Instruments And Hedging Activities Disclosure [Abstract]

'

Schedule of Fair Value of Derivative Contracts

'

The following table summarizes the fair values of TEP’s derivative contracts included in the accompanying Condensed Consolidated Balance Sheets:

Balance Sheet

March 31, 2014

December 31, 2013

Location

(in thousands)

Energy commodity derivative contracts

Current liabilities

$

535

$

184

Derivative Contracts Included in Consolidated Statements of Income

'

The following table summarizes the impact of derivative contracts included in the accompanying Condensed Consolidated Statements of Income and Comprehensive Income for the three months ended March 31, 2014 and 2013:

Amount of loss recognized in

income on derivatives

Location of

Three Months

Three Months

loss recognized

Ended

Ended

in income on

March 31,  2014

March 31,  2013

derivatives

(in thousands)

(in thousands)

Derivatives not designated as hedging contracts:

Energy commodity derivative contracts

Natural gas sales

$

(351

)

$

(919

)

Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification

'

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

Liability fair value measurements using

Total

Quoted prices in

Significant

Significant

active markets

other observable

unobservable

for identical

inputs

inputs

assets

(Level 2)

(Level 3)

(Level 1)

(in thousands)

TEP as of March 31, 2014

Energy commodity derivative contracts

$

535

$

—

$

535

$

—

TEP as of December 31, 2013

Energy commodity derivative contracts

$

184

$

—

$

184

$

—

Longterm_Debt_Tables

Long-term Debt (Tables)	3 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
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 March 31, 2014 and December 31, 2013, but for which fair value is disclosed:
		Fair Value
		Quoted prices		Significant		Significant		Total		Carrying
		in active markets		other observable		unobservable				Amount
		for identical assets		inputs		inputs
		(Level 1)		(Level 2)		(Level 3)
		(in thousands)
	31-Mar-14	$	—	$	135,000	$	—	$	135,000	$	135,000
	31-Dec-13	$	—	$	135,000	$	—	$	135,000	$	135,000

Partnership_Equity_and_Distrib1

Partnership Equity and Distributions (Tables)	3 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
Summary of Distributions	'
	The following table shows the distributions for the year ended 2013 and three months ended March 31, 2014:
				Distributions
				LimitedPartners		General Partner						Distributions
				Common and								per Limited
	Three Months Ended		Date Paid	Subordinated		Incentive		2%		Total		Partner Unit
				(in thousands, except per unit amounts)
	March 31, 2014		May 14, 2014(2)	$	13,288	$	126	$	274	$	13,688	$	0.325
	December 31, 2013		February 12, 2014		12,757		63		262		13,082		0.315
	September 30, 2013		November 13, 2013		12,049		—		245		12,294		0.2975
	June 30, 2013		13-Aug-13		5,759		—		118		5,877		0.1422	(1)
	(1)	The distribution declared on July 18, 2013 for the second quarter of 2013 represented a prorated amount of the MQD of $0.2875 per common unit, based upon the number of days between the closing of the IPO on May 17, 2013 to June 30, 2013.
	(2)	The distribution declared on April 1, 2014 for the first quarter of 2014 is expected to be paid May 14, 2014 subsequent to the date of this Quarterly Report to 40,885,140 common unitholders of record at the close of business on April 30, 2014.

Net_Income_per_Limited_Partner1

Net Income per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Summary of Net Income Per Limited Partner Unit	'
	The following table illustrates the Partnership’s calculation of net income per common and subordinated unit for the three months ended March 31, 2014:
		Three Months
		Ended
		March 31, 2014
		(in thousands, except
		per unit amounts)
	Net Income	$	12,900
	General partner interest in net income		382
	Net income available to common and subordinated unitholders	$	12,518
	Basic net income per common and subordinated unit	$	0.31
	Diluted net income per common and subordinated unit	$	0.3
	Basic average number of common and subordinated units outstanding		40,500
	Equity Participation Unit equivalent units		772
	Diluted average number of common and subordinated units outstanding		41,272

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2014
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 months ended March 31, 2014:
		Three Months Ended March 31, 2014
		Shares			Weighted Average
					Grant Date Fair Value
	Beginning of period	$	1,474,250		$	17.54
	Granted		31,500			23.68
	Forfeited		(19,000	)		(17.49	)
	End of period	$	1,486,750		$	17.67

Reporting_Segments_Tables

Reporting Segments (Tables)	3 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Summary of TEP's Segment Information of Revenue	'
		Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
		Total			Inter-		External			Total		Inter-			External
		Revenue			Segment		Revenue			Revenue		Segment			Revenue
					(in thousands)							(in thousands)
	Gas transportation and storage	$	28,559		$	—	$	28,559		$	23,597	$	(171	)	$	23,426
	Processing		56,403			—		56,403			36,832		—			36,832
	Corporate and other		—			—		—			—		—			—
	Total revenue	$	84,962		$	—	$	84,962		$	60,429	$	(171	)	$	60,258
Summary of TEP's Segment Information of Earnings	'
		Three Months Ended March 31, 2014								Three Months Ended March 31, 2013
		Total					External			Total					External
		Adjusted			Inter-		Adjusted			Adjusted		Inter-			Adjusted
		EBITDA			Segment		EBITDA			EBITDA		Segment			EBITDA
					(in thousands)							(in thousands)
	Gas transportation and storage	$	13,123		$	—	$	13,123		$	12,266	$	(171	)	$	12,095
	Processing		9,596			—		9,596			6,834		171			7,005
	Corporate and other		(625	)		—		(625	)		—		—			—
	Reconciliation to Net Income:
	Interest expense (income), net							1,324								5,564
	Depreciation and amortization expense							6,514								7,546
	Non-cash loss (gain) related to derivative instruments							351								919
	Non-cash compensation expense							941								—
	Distributions from unconsolidated investment							508								—
	Equity in earnings of unconsolidated investment							(444	)							—
	Net Income						$	12,900							$	5,071
Summary of TEP's Segment Information of Assets	'
		Total Assets
		March 31, 2014			December 31, 2013
		(in thousands)
	Gas transportation and storage	$	627,894		$	636,686
	Processing		326,886			326,599
	Corporate and other		4,297			4,513
	Total assets	$	959,077		$	967,798

Description_of_Business_Additi

Description of Business - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	17-May-13
Organization [Line Items]	'	'	'
General partner interest in TEP	2.00%	'	'
General partner units issued to Tallgrass MLP GP, LLC (the "GP")	826,531	826,531	826,531
TEP Predecessor [Member]	'	'	'
Organization [Line Items]	'	'	'
Gas transmission lines owned	4,645	'	'
Ownership Interests Held By Public [Member]	'	'	'
Organization [Line Items]	'	'	'
Aggregate outstanding common, subordinated and general partner units	35.00%	'	'
Aggregate outstanding common and subordinated units	36.00%	'	'
Initial public offering of common units	14,600,000	'	'
Ownership Interests Held By TD [Member]	'	'	'
Organization [Line Items]	'	'	'
Aggregate outstanding common, subordinated and general partner units	63.00%	'	'
Aggregate outstanding common and subordinated units	64.00%	'	'
Common and subordinated units issued, units	9,700,000	'	'
Subordinated unit	16,200,000	'	'

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	12 Months Ended				3 Months Ended		12 Months Ended
	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2014
	Miles		Pony Express Project [Member]	Pony Express Project [Member]	Pony Express Project [Member]	Scenario [Member]	Scenario, Forecast [Member]
			TEP [Member]	TEP [Member]	TD [Member]	Public Company Expense [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'	'
Expected public company cost reimbursement	'	'	'	'	'	$625,000	'
Expected general administrative expense reimbursement	'	'	'	'	'	'	19,900,000
Gas transmission lines sold	430	'	'	'	'	'	'
Prepayments and other current assets	16,986,000	4,264,000	4,000,000	17,000,000	'	'	'
Reimbursable expenses related to construction of Gas Facilities	'	'	'	'	26,200,000	'	'
Capital expenditures reimbursement from related party	'	'	'	'	$22,200,000	'	'

Related_Party_Transactions_Sch

Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operation and maintenance [Member]	'	'
Related Party Transaction [Line Items]	'	'
Expenses related to transactions with affiliated companies	$3,840	$3,586
General and administrative [Member]	'	'
Related Party Transaction [Line Items]	'	'
Expenses related to transactions with affiliated companies	4,224	4,634
Property, plant and equipment, net [Member]	'	'
Related Party Transaction [Line Items]	'	'
Costs Capitalized related to transactions with affiliated companies	5,316	4,709
Other deferred charges [Member]	'	'
Related Party Transaction [Line Items]	'	'
Costs Capitalized related to transactions with affiliated companies	$582	$1,038

Related_Party_Transactions_Sch1

Related Party Transactions - Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Total accounts receivable from affiliated companies	$29	'
Accounts payable to affiliated companies	3,655	7,134
Total payables to affiliated companies	3,655	7,134
Rockies Express Pipeline LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total accounts receivable from affiliated companies	29	'
Accounts payable to affiliated companies	'	28
Tallgrass Operations, LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable to affiliated companies	$3,655	$7,106

Related_Party_Transactions_Sch2

Related Party Transactions - Schedule of Balances of Gas Imbalance with Affiliated Shippers (Detail) (Affiliated Shippers [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Affiliated Shippers [Member]	'	'
Related Party Transaction [Line Items]	'	'
Affiliate gas balance receivables	'	$7
Affiliate gas balance payables	$1,633	$116

Inventory_Schedule_of_Componen

Inventory - Schedule of Components of Inventory (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Materials and supplies	$1,730	$1,736
Natural gas liquids	1,164	1,009
Gas in underground storage	8,458	2,403
Total inventory	$11,352	$5,148

Property_Plant_and_Equipment_C

Property Plant and Equipment - Components of Property Plant and Equipment (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation and amortization	($22,907)	($18,076)
Total property, plant and equipment, net	593,301	594,911
Natural gas pipelines [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	348,481	339,430
Processing & Treating [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	234,541	209,329
General and other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	25,202	24,859
Construction work in progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property , plant and equipment	$7,984	$39,369

Risk_Management_Schedule_of_Fa

Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) (Energy commodity derivative contracts [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Total derivative liabilities	$535	$184
Current liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Total derivative liabilities	$535	$184

Risk_Management_Additional_Inf

Risk Management - Additional Information (Detail) (Commodity [Member])	Mar. 31, 2014
	Bcf
Commodity [Member]	'
Derivative [Line Items]	'
Derivative volumes	0.9

Risk_Management_Derivative_Con

Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) (Derivatives not designated as hedging contracts [Member], Energy commodity derivative contracts [Member], USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Derivatives not designated as hedging contracts [Member] | Energy commodity derivative contracts [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Amount of loss recognized in income on derivatives	($351)	($919)
Location of loss recognized in income on derivatives	'Natural gas sales	'Natural gas sales

Risk_Management_Schedule_of_En

Risk Management - Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification (Detail) (Energy commodity derivative contracts [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	$535	$184
Quoted prices in active markets for identical assets (Level 1) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	'	'
Significant other observable inputs (Level 2) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	535	184
Significant unobservable inputs (Level 3) [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Energy commodity derivative contracts	'	'

Longterm_Debt_Additional_Infor

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

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Mar. 31, 2014

17-May-13

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

17-May-13

Nov. 13, 2012

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Senior Revolving Credit Facility [Member]

Maximum [Member]

Minimum [Member]

Normal [Member]

Certain Acquisition Waiver [Member]

TEP Pre-Predecessor [Member]

TEP Pre-Predecessor [Member]

Barclays Bank [Member]

Maximum [Member]

Maximum [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity under new credit agreement

'

'

$500

'

'

$500

'

'

'

'

'

'

Credit facility maturity date

'

'

'

'

'

17-May-18

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

'

'

135

135

'

'

'

'

'

'

'

Debt issued

'

'

'

0.7

0.7

'

'

'

'

'

'

'

Revolving credit facility remaining borrowing capacity

'

'

'

364.3

364.3

'

'

'

'

'

'

'

Consolidated leverage ratio

'

'

'

'

'

'

'

'

4.75

5.25

'

'

Consolidated interest coverage ratio

'

'

'

'

'

'

'

2.5

'

'

'

'

Credit facility commitment fee

'

'

'

'

'

'

0.50%

0.38%

'

'

'

'

Weighted average interest rate on outstanding borrowings

'

2.15%

'

'

'

'

'

'

'

'

'

'

Business combination, long-term debt

'

'

'

'

'

'

'

'

'

'

400

400

Loss on extinguishment of debt

$17.50

'

'

'

'

'

'

'

'

'

'

'

Longterm_Debt_Carrying_Amount_

Long-term Debt - Carrying Amount and Fair Value of TEP's Long-term Debt (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Fair Value	$135,000	$135,000
Carrying Amount	135,000	135,000
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	135,000	135,000
Significant unobservable inputs (Level 3) [Member]	'	'
Debt Instrument [Line Items]	'	'
Fair Value	'	'

Partnership_Equity_and_Distrib2

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

3 Months Ended

3 Months Ended

3 Months Ended

In Millions, except Share data, unless otherwise specified

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

17-May-13

Mar. 31, 2014

Mar. 31, 2013

Apr. 01, 2014

Mar. 31, 2014

Jun. 30, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

TD [Member]

TD [Member]

Subsequent Event [Member]

Minimum Quarterly Distribution [Member]

Minimum Quarterly Distribution [Member]

Second Target Distribution [Member]

Third Target Distribution [Member]

First Target Distribution [Member]

Thereafter [Member]

Trailblazer [Member]

Limited Partners' Capital Account [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum Quarterly Distribution to Common unit holder

$0.33

$0.32

$0.30

$0.14

'

'

'

'

$0.29

$0.29

'

'

'

'

Additional contribution of general partner units

826,531

826,531

'

'

826,531

'

'

7,860

'

'

'

'

'

'

General partner interest in TEP

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Increasing incentive distribution right

'

'

'

'

'

'

'

'

'

'

13.00%

23.00%

'

48.00%

Incentive distribution per unit

'

'

'

'

'

'

'

'

'

'

$0.35

$0.43

$0.30

'

Percentage of unit holders

'

'

'

'

'

'

'

'

'

'

85.00%

75.00%

98.00%

50.00%

Percentage of general partner

'

'

'

'

'

'

'

'

'

'

15.00%

25.00%

2.00%

50.00%

Distributions to Affiliates

'

'

'

'

'

$0

$23.10

'

'

'

'

'

'

'

Partnership_Equity_and_Distrib3

Partnership Equity and Distributions - Summary of Distributions (Detail) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013
Distribution Made to Limited Partner [Line Items]	'	'	'	'
Date Paid	14-May-14	12-Feb-14	13-Nov-13	13-Aug-13
Distributions Limited Partners Common	$13,288	$12,757	$12,049	$5,759
Distributions declared	13,688	13,082	12,294	5,877
Distributions per Limited Partner Unit	$0.33	$0.32	$0.30	$0.14
General Partner [Member]	'	'	'	'
Distribution Made to Limited Partner [Line Items]	'	'	'	'
Distributions General Partner Incentive	126	63	'	'
Distributions declared	$274	$262	$245	$118

Partnership_Equity_and_Distrib4

Partnership Equity and Distributions - Summary of Distributions (Parenthetical) (Detail) (USD $)	3 Months Ended				0 Months Ended	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Apr. 01, 2014	Mar. 31, 2014	Jun. 30, 2013
					Subsequent Event [Member]	Minimum Quarterly Distribution [Member]	Minimum Quarterly Distribution [Member]
Distribution Made to Limited Partner [Line Items]	'	'	'	'	'	'	'
Minimum Quarterly Distribution to Common unit holder	$0.33	$0.32	$0.30	$0.14	'	$0.29	$0.29
Distribution declared to common unit holders	'	'	'	'	40,885,140	'	'

Net_Income_per_Limited_Partner2

Net Income per Limited Partner Unit - Summary of Net Income Per Limited Partner Unit (Detail) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Earnings Per Share [Abstract]	'	'
Net Income	$12,900	$5,071
General partner interest in net income	382	'
Net income available to common and subordinated unitholders	$12,518	'
Basic net income per common and subordinated unit	$0.31	'
Diluted net income per common and subordinated unit	$0.30	'
Basic average number of common and subordinated units outstanding	40,500	'
Equity Participation Unit equivalent units	772	'
Diluted average number of common and subordinated units outstanding	41,272	'

Equity_Based_Compensation_Addi

Equity Based Compensation - Additional Information (Detail) (USD $)	0 Months Ended	3 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 26, 2013	Mar. 31, 2014
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
LTIP expiration period	'	13-May-23
Share-based compensation expense related to the EPU grants recognized	'	2.2
Compensation cost related to nonvested EPUs expected to be recognized	'	17.1
Weighted average period in which compensation cost related to nonvested EPUs expected to be recognized	'	'2 years 6 months
Maximum [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Equity participation units granted	'	10,000,000
TEP [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Share-based compensation expense related to the EPU grants recognized	'	0.9
Equity Participation Unit [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Equity participation units granted	1,490,000	31,500
Equity Participation Unit [Member] | Maximum [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Equity participation units granted	1,500,000	'
Equity Participation Unit [Member] | Section 16 Officers [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Equity participation units granted	177,500	'
Equity Participation Unit [Member] | Pony Express Project [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Pony Express gas transmission lines converted to oil	690	'

Equity_Based_Compensation_Summ

Equity Based Compensation - Summarizes Changes in EPUs Outstanding (Detail) (Equity Participation Unit [Member], USD $)	0 Months Ended	3 Months Ended
	Jun. 26, 2013	Mar. 31, 2014
Equity Participation Unit [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Beginning of period, Shares	'	1,474,250
Granted, Shares	1,490,000	31,500
Forfeited, Shares	'	-19,000
End of period, Shares	'	1,486,750
Beginning of period, Weighted Average Grant Date Fair Value	'	$17.54
Granted, Weighted Average Grant Date Fair Value	'	$23.68
Forfeited, Weighted Average Grant Date Fair Value	'	($17.49)
End of period, Weighted Average Grant Date Fair Value	'	$17.67

Legal_and_Environmental_Matter1

Legal and Environmental Matters - Additional Information (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014
In Millions, unless otherwise specified			TEP [Member]
Loss Contingencies [Line Items]	'	'	'
Aggregate reserves for all claims	$0.60	$0.30	'
Budgeted cost of remediation activities related to Goshen county failure	'	'	0.5
Environmental accruals	$4.90	$5	'

Reporting_Segments_Additional_

Reporting Segments - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2014
	Segment
Segment Reporting [Abstract]	'
Number of reportable segments	2

Reporting_Segments_Summary_of_

Reporting Segments - Summary of TEP's Segment Information of Revenue (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Segment Reporting Information [Line Items]	'	'
Sales and revenues	$84,962	$60,258
Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	28,559	23,426
Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	56,403	36,832
Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	'
Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	84,962	60,429
Operating Segments [Member] | Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	28,559	23,597
Operating Segments [Member] | Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	56,403	36,832
Operating Segments [Member] | Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	'
Inter-Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	-171
Inter-Segment [Member] | Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	-171
Inter-Segment [Member] | Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	'
Inter-Segment [Member] | Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Sales and revenues	'	'

Reporting_Segments_Summary_of_1

Reporting Segments - Summary of TEP's Segment Information of Earnings (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Reconciliation to Net Income:	'	'
Interest expense (income), net	$1,324	$5,564
Depreciation and amortization expense	6,514	7,546
Non-cash loss (gain) related to derivative instruments	351	919
Non-cash compensation expense	941	'
Distributions from unconsolidated investment	508	'
Equity in earnings of unconsolidated investment	-444	'
Net Income	12,900	5,071
Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	13,123	12,095
Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	9,596	7,005
Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	-625	'
Operating Segments [Member] | Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	13,123	12,266
Operating Segments [Member] | Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	9,596	6,834
Operating Segments [Member] | Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	-625	'
Inter-Segment [Member] | Gas Transportation and Storage Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	'	-171
Inter-Segment [Member] | Processing Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	'	171
Inter-Segment [Member] | Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Adjusted EBITDA	'	'
Segment Reconciling Items [Member]	'	'
Reconciliation to Net Income:	'	'
Interest expense (income), net	1,324	5,564
Depreciation and amortization expense	6,514	7,546
Non-cash loss (gain) related to derivative instruments	351	919
Non-cash compensation expense	941	'
Distributions from unconsolidated investment	508	'
Equity in earnings of unconsolidated investment	-444	'
Net Income	$12,900	$5,071

Reporting_Segments_Summary_of_2

Reporting Segments - Summary of TEP's Segment Information of Assets (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Segment Reporting Information [Line Items]	'	'
Segment assets	$959,077	$967,798
Gas Transportation and Storage Segment [Member] | Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	627,894	636,686
Processing Segment [Member] | Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	326,886	326,599
Corporate and Other [Member] | Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Segment assets	$4,297	$4,513

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013	17-May-13	Mar. 31, 2014	Apr. 01, 2014
				Trailblazer [Member]	Subsequent Event [Member]
					Trailblazer [Member]
Subsequent Event [Line Items]	'	'	'	'	'
Date of acquisition	'	'	'	1-Apr-14	'
Total transaction value	'	'	'	'	$164,000,000
Purchase consideration as issuance of common shares	'	'	'	'	385,140
Common units value	'	'	'	'	14,000,000
Purchase consideration in cash	'	'	'	'	150,000,000
Partners capital units issued	826,531	826,531	826,531	'	7,860
Additional capital contributed related to acquisition	'	'	'	'	$263,000
Maintenance of general partners interest	'	'	'	'	2.00%