Sabine Pass LNG 10-K 20 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass LNG, L.P.
Entity Central Index Key	1379714
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding	0
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float		$0

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$5,460	$14,994
Restricted cash and cash equivalents	14,959	14,959
Accounts receivable—affiliate	1,055	2,615
Advances to affiliate	1,868	4,025
LNG inventory	1,987	10,430
Prepaid expenses and other	4,301	5,149
Total current assets	29,630	52,172
Non-current restricted cash and cash equivalents	76,106	76,106
Property, plant and equipment, net	1,392,443	1,433,822
Debt issuance costs, net	12,643	16,871
Other non-current assets	19,802	17,239
Total assets	1,530,624	1,596,210
Current liabilities
Accounts payable	408	1,420
Accrued liabilities	16,036	21,153
Due to affiliates	2,266	18,721
Deferred revenue	26,655	26,593
Deferred revenue—affiliate	21,839	21,786
Total current liabilities	67,204	89,673
Long-term debt, net of discount	2,076,502	2,071,807
Non-current deferred revenue	13,500	17,500
Non-current deferred revenue—affiliate	19,626	17,173
Other non-current liabilities	263	276
Commitments and contingencies
Partners’ deficit	-646,471	-600,219
Total liabilities and partners’ deficit	$1,530,624	$1,596,210

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues
Revenues	$265,947	$265,153	$268,273
Revenues—affiliate	256,760	256,399	255,611
Total revenues	522,707	521,552	523,884
Operating costs and expenses
Operating and maintenance expense	31,306	32,724	25,399
Operating and maintenance expense, net—affiliate	16,830	25,172	16,032
Depreciation expense	42,465	42,444	42,431
General and administrative expense	2,148	2,844	1,864
General and administrative expense—affiliate	12,499	13,264	10,790
Total operating costs and expenses	105,248	116,448	96,516
Income from operations	417,459	405,104	427,368
Other income (expense)
Interest expense	-161,135	-161,041	-171,495
Loss on early extinguishment of debt	0	0	-42,587
Derivative gain (loss), net	529	182	-622
Other income	36	48	141
Total other expense	-160,570	-160,811	-214,563
Net income	$256,889	$244,293	$212,805

Consolidated_Statements_of_Par

Consolidated Statements of Partners' Deficit (USD $)	3 Months Ended				12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Partners' Capital, Beginning of Period		($600,219)		($552,394)	($600,219)	($552,394)	($643,596)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	62,858	64,271	62,071	61,854	256,889	244,293	212,805
Capital contributions from Cheniere Partners					43,015	56,820	211,850
Non-cash contributions from limited partner					745
Distributions to limited partner					-346,901	-348,938	-333,453
Partners' Capital, End of Period	-646,471		-600,219		-646,471	-600,219	-552,394
General Partner Sabine Pass LNG-GP, LLC [Member]
Partners' Capital, Beginning of Period		0		0	0	0	0
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income					0	0	0
Capital contributions from Cheniere Partners					0	0	0
Non-cash contributions from limited partner					0
Distributions to limited partner					0	0	0
Partners' Capital, End of Period	0		0		0	0	0
Limited Partner Sabine Pass LNG-LP, LLC [Member]
Partners' Capital, Beginning of Period		-600,219		-552,394	-600,219	-552,394	-643,596
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income					256,889	244,293	212,805
Capital contributions from Cheniere Partners					43,015	56,820	211,850
Non-cash contributions from limited partner					745
Distributions to limited partner					-346,901	-348,938	-333,453
Partners' Capital, End of Period	($646,471)		($600,219)		($646,471)	($600,219)	($552,394)

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net income	$256,889	$244,293	$212,805
Adjustments to reconcile net income to net cash provided by operating activities:
Use of (investment in) restricted cash and cash equivalents for certain operating activities	0	2,427	-3,654
Depreciation	42,465	42,444	42,431
Loss on early extinguishment of debt	0	0	1,470
Amortization of debt issuance costs and discount	8,922	8,904	9,057
Other, net	22	44	2,179
Changes in operating assets and liabilities:
Accounts payable and accrued liabilities	-6,138	-751	2,296
Due to affiliates	-16,456	12,512	482
Deferred revenue	-3,938	-3,947	-4,089
Advances to affiliate	2,157	-2,983	-487
Accounts and interest receivable	37	-31	511
Accounts receivable—affiliate	1,561	-1,266	-1,035
Other, net	6,677	529	1,242
Other, net—affiliate	2,502	49	87
Net cash provided by operating activities	294,700	302,224	263,295
Cash flows from investing activities
Property, plant and equipment, net	-348	-116	-4,458
Net cash used in investing activities	-348	-116	-4,458
Cash flows from financing activities
Distributions to limited partner	-346,901	-348,938	-333,453
Capital contributions from Cheniere Partners	43,015	56,820	208,354
Repayment of long-term debt	0	0	-550,000
Proceeds from issuance of long-term debt	0	0	420,000
Debt issuance costs	0	-198	-9,092
Use of restricted cash and cash equivalents	0	0	6,288
Net cash used in financing activities	-303,886	-292,316	-257,903
Net increase (decrease) in cash and cash equivalents	-9,534	9,792	934
Cash and cash equivalents—beginning of period	14,994	5,202	4,268
Cash and cash equivalents—end of period	$5,460	$14,994	$5,202

Organization_and_Nature_of_Ope

Organization and Nature of Operations (Notes)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	ORGANIZATION AND NATURE OF OPERATIONS
	We are a Houston-based Delaware limited partnership formed by Cheniere Energy, Inc. (“Cheniere”) to own, develop and operate an LNG receiving and regasification terminal in western Cameron Parish, Louisiana, less than four miles from the Gulf Coast on the Sabine Pass deepwater ship channel (our “LNG terminal”). We were formed with one general partner, Sabine Pass LNG-GP, LLC (“Sabine Pass GP”), and one limited partner, Sabine Pass LNG-LP, LLC (“Sabine Pass LP”), both indirect subsidiaries of Cheniere. Cheniere has an 80.1% ownership in Cheniere Energy Partners LP Holdings, LLC, which in turn has a 55.9% ownership interest in Cheniere Energy Partners, L.P. (“Cheniere Partners”). Cheniere Partners is the 100% parent of Cheniere Energy Investments, LLC (“Cheniere Investments”), which in turn is the 100% parent of Sabine Pass GP and Sabine Pass LP and, indirectly, us.
	Our LNG terminal includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d.
	Unless the context requires otherwise, references to “Sabine Pass LNG,” “we,” “us” and “our” refer to Sabine Pass LNG, L.P. and its wholly owned subsidiary.

Summary_of_Significant_Account

Summary of Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Basis of Presentation
	Our Consolidated Financial Statements were prepared in accordance with generally accepted accounting principles in the United States (“GAAP”). Our Consolidated Financial Statements include the accounts of Sabine Pass LNG and its wholly owned subsidiary. All intercompany accounts and transactions have been eliminated in consolidation.
	Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.
	Use of Estimates
	The preparation of Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
	Fair Value
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.
	In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates.
	Recurring fair-value measurements are performed for commodity derivatives as disclosed in Note 5—Derivative Instruments. The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Consolidated Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 7—Long-Term Debt, are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments. Non-financial assets and liabilities initially measured at fair value include certain assets and liabilities acquired in a business combination, intangible assets and AROs.
	Revenue Recognition
	LNG regasification capacity reservation fees are recognized as revenue over the term of the TUAs. Advance capacity reservation fees are initially deferred and amortized over a 10-year period as a reduction of a customer’s regasification capacity reservation fees payable under its TUA.  For a discussion of revenue from related parties, please read Note 8—Related Party Transactions.  Under each of these TUAs, Sabine Pass LNG is entitled to retain 2% of LNG delivered for each customer’s account at our LNG terminal, which is recognized as revenue as we perform the services set forth in each customer’s TUA.
	Cash and Cash Equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
	Accounting for LNG Activities
	Generally, we begin capitalizing the costs of our LNG terminal projects once the individual project meets the following criteria: (i) regulatory approval has been received, (ii) financing for the project is available and (iii) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a project are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to our LNG terminal projects.
	Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as intangible LNG assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed.
	We capitalize interest and other related debt costs during the construction period of our LNG terminal. Upon commencement of operations, capitalized interest, as a component of the total cost, will be amortized over the estimated useful life of the asset.
	Property, Plant and Equipment
	Property, plant and equipment are recorded at cost. Expenditures for construction activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses.
	Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. In performing this test, an undiscounted cash flow analysis is performed at the lowest level for which identifiable cash flows are independent of cash flows from other assets. If the sum of the undiscounted future net cash flows is less than the net book value of the property, an impairment loss is recognized for the excess, if any, of the property’s net book value over its estimated fair value. We have recorded no impairments related to property, plant and equipment for 2014, 2013 or 2012.
	Derivative Instruments
	We use derivative instruments to hedge our exposure to cash-flow variability from commodity price risk.
	Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria, and we elect, the normal purchases and sales exception. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis.
	Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did not have any derivative instruments designated as cash flow hedges as of December 31, 2014 and 2013.
	See Note 5—Derivative Instruments of our Notes to Consolidated Financial Statements for additional details about our derivative instruments.
	Concentration of Credit Risk
	Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date.
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as an other current asset and not netted within the derivative fair value. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments.
	We have entered into certain long-term TUAs with unaffiliated third parties for regasification capacity at our LNG terminal. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective TUAs. We have mitigated this credit risk by securing TUAs for a significant portion of our regasification capacity with creditworthy third-party customers with a minimum Standard & Poor’s rating of AA.
	Long-Term Debt
	Our debt consists of long-term secured debt securities with banks and other lenders.  Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors.
	Debt is recorded on our balance sheet at par value adjusted for unamortized discount or premium. Discounts, premiums and costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Consolidated Statements of Income.
	Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as debt issuance costs on our Consolidated Balance Sheets and are being amortized to interest expense over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off as loss on early extinguishment of debt.
	Income Taxes
	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Consolidated Financial Statements.
	At December 31, 2014, the tax basis of our assets and liabilities was $460.3 million less than the reported amounts of our assets and liabilities.
	Pursuant to the indentures governing our long-term debt (the “Senior Notes Indentures”), we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The permitted Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the State Tax Sharing Agreement discussed immediately below. The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
	In November 2006, we and Cheniere entered into a state tax sharing agreement. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were computed on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after January 1, 2008.
	Asset Retirement Obligations
	We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our recognition of AROs is described below.
	Based on the real property lease agreements at our LNG terminal, at the expiration of the term of the leases, we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at our LNG terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender our LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero. Therefore, we have not recorded an ARO associated with our LNG terminal.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents (Notes)	12 Months Ended
	Dec. 31, 2014
Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS
	Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal, are controlled by a collateral trustee and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets.
	We have consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of 7.50% Senior Secured Notes due 2016 (the “2016 Senior Notes”) and $420.0 million of 6.50% Senior Secured Notes due 2020 (the “2020 Senior Notes”) See Note 7—Long-Term Debt. Collectively, the 2016 Senior Notes and the 2020 Senior Notes are referred to as the “Senior Notes.” Under the Senior Notes Indentures, except for permitted tax distributions, we may not make distributions until certain conditions are satisfied, including: (i) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (ii) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass LNG Indentures.
	As of both December 31, 2014 and 2013, we classified $15.0 million as current restricted cash and cash equivalents for the payment of current interest due. As of both December 31, 2014 and 2013, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash and cash equivalents.

Property_Plant_and_Equipment_N

Property Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	1,643,018		$	1,642,007
	LNG terminal construction-in-process	27			9
	LNG site and related costs, net	142			149
	Accumulated depreciation	(250,954		)	(208,729		)
	Total LNG terminal costs, net	1,392,233			1,433,436
	Fixed assets
	Machinery and equipment	1,169			1,189
	Computer and office equipment	424			424
	Vehicles	654			599
	Other	697			697
	Accumulated depreciation	(2,734		)	(2,523		)
	Total fixed assets, net	210			386
	Property, plant and equipment, net	$	1,392,443		$	1,433,822
	Our LNG terminal is depreciated using the straight-line depreciation method applied to groups of LNG terminal assets with varying useful lives. The identifiable components of our LNG terminal with similar estimated useful lives have a depreciable range between 15 and 50 years, as follows:
	Components		Useful life (yrs)
	LNG storage tanks		50
	Marine berth, electrical, facility and roads		35
	Regasification processing equipment (recondensers, vaporization and vents)		30
	Sendout pumps		20
	Others		15-30

Derivative_Instruments_Notes

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS
	We have entered into certain derivative instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory (“LNG Inventory Derivatives”) and to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal (“Fuel Derivatives”).
	The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of December 31, 2014 and 2013, which are classified as prepaid expenses and other in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		31-Dec-14															31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total			Quoted Prices in Active Markets			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
		(Level 1)															(Level 1)
	LNG Inventory	$	—			$	145			$	—			$	145		$	—		$	—		$	—	$	—
	Derivatives asset
	Fuel Derivatives asset	—				—				—				—			—			27			—		27
	The estimated fair values of our LNG Inventory Derivatives and Fuel Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for net settlement.
	We recognize all derivative instruments that qualify for derivative accounting treatment, including our LNG Inventory Derivatives and Fuel Derivatives, as either assets or liabilities and measure those instruments at fair value unless they qualify for, and we elect, the normal purchase normal sale exception. For those instruments accounted for as derivatives, including all of our LNG Inventory Derivatives as of December 31, 2014, changes in fair value are reported in earnings.  For transactions in which we have elected the normal purchase normal sale exception, including all of our Fuel Derivatives as of December 31, 2014, gains and losses are not reflected on our Consolidated Statements of Income until the period of delivery.
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances where our Fuel Derivatives or our LNG Inventory Derivatives are in an asset position. Except for the Fuel Derivatives with our affiliate described below, our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for these commodity derivative activities. We had a collateral call of $0.1 million and a collateral deposit of $0.7 million for such contracts, which have not been reflected in the derivative fair value tables, but are included in the other current assets balance as of December 31, 2014 and 2013, respectively.
	During the second quarter of 2013, we began to enter into forward contracts under an International Swaps and Derivatives Association master agreement with Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly owned subsidiary of Cheniere, to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate our terminal. We elected to account for these physical hedges of future fuel purchases as normal purchase normal sale transactions, exempt from fair value accounting. We had not posted collateral with Cheniere Marketing for such forward contracts as of December 31, 2014.
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			December 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	145			$	—
	Fuel Derivatives asset	Prepaid expenses and other			—				27
	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Income during the years ended December 31, 2014, 2013 and 2012:
				Year Ended December 31,
				2014				2013				2012
	LNG Inventory Derivatives gain			$	247			$	—			$	—
	Fuel Derivatives gain (loss) (1)			281				182				(622		)
	-1	Excludes settlements of our Fuel Derivatives with Cheniere Marketing for which we have elected the normal purchase normal sale exception from derivative accounting and have recorded as operating and maintenance expense.
	Balance Sheet Presentation
	Our LNG Inventory Derivatives and Fuel Derivatives are presented on a net basis on our Consolidated Balance Sheets as described above. The following table (in thousands) shows the fair value of our LNG Inventory Derivatives and Fuel Derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amounts Presented in the Consolidated Balance Sheets				Gross Amounts Not Offset in the Consolidated Balance Sheets
	Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
	As of December 31, 2014:
	LNG Inventory Derivatives		$	145			$	132			$	13			$	—		$	—		$	13
	As of December 31, 2013:
	Fuel Derivatives		27				—				27				—			—			27

Accrued_Liabilities_Notes

Accrued Liabilities (Notes)	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES
	As of December 31, 2014 and 2013, accrued liabilities consisted of the following (in thousands):
		December 31,
		2014		2013
	Interest expense and related debt fees	$	14,959	$	14,959
	LNG terminal costs	1,077		1,612
	Other	—		4,582
	Total accrued liabilities	$	16,036	$	21,153

LongTerm_Debt_Notes

Long-Term Debt (Notes)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-term Debt	LONG-TERM DEBT
	As of December 31, 2014 and 2013, our long-term debt consisted of the following (in thousands):
			December 31,
			2014				2013
	Long-term debt
	2016 Senior Notes		$	1,665,500			$	1,665,500
	2020 Senior Notes		420,000				420,000
	Total long-term debt		2,085,500				2,085,500
	Long-term debt discount
	2016 Senior Notes		(8,998		)		(13,693		)
	Total long-term debt, net		$	2,076,502			$	2,071,807
	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2014 (in thousands):
			Payments Due for the Years Ended December 31,
			Total				2015				2016 to 2017			2018 to 2019		Thereafter
	Debt:
	2016 Notes		$	1,665,500			$	—			$	1,665,500		$	—	$	—
	2020 Notes		420,000				—				—			—		420,000
	Debt		$	2,085,500			$	—			$	1,665,500		$	—	$	420,000
	Senior Notes
	As of both December 31, 2014 and 2013, we had an aggregate principal amount of $1,665.5 million, before discount, of the 2016 Senior Notes and $420.0 million of the 2020 Senior Notes outstanding. Borrowings under the 2016 Senior Notes and 2020 Senior Notes bear interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Senior Notes and the 2020 Senior Notes are substantially similar. Interest on the Senior Notes is payable semi-annually in arrears. Subject to permitted liens, the Senior Notes are secured on a first-priority basis by a security interest in all of our equity interests and substantially all of our operating assets.
	We may redeem all or part of our 2016 Senior Notes at any time, and from time to time, at a redemption price equal to 100% of the principal plus any accrued and unpaid interest plus the greater of:
	•	1.0% of the principal amount of the 2016 Senior Notes; or
	•	the excess of: a) the present value at such redemption date of (i) the redemption price of the 2016 Senior Notes plus (ii) all required interest payments due on the 2016 Senior Notes (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 50 basis points; over b) the principal amount of the 2016 Senior Notes, if greater.
	We may redeem all or part of our 2020 Senior Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020 Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. We may also, at our option, redeem all or part of the 2020 Senior Notes at any time prior to November 1, 2016, at a “make-whole” price set forth in the indenture governing the 2020 Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, we may redeem up to 35% of the aggregate principal amount of the 2020 Senior Notes at a redemption price of 106.5% of the principal amount of the 2020 Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the redemption date, in an amount not to exceed the net proceeds of one or more completed equity offerings as long as we redeem the 2020 Senior Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Senior Notes originally issued remains outstanding after the redemption.
	Under the Sabine Pass LNG Indentures, except for permitted tax distributions, we may not make distributions until certain conditions are satisfied as described in Note 3—Restricted Cash and Cash Equivalents. During the years ended December 31, 2014, 2013 and 2012 we made distributions of $346.9 million, $348.9 million and $333.5 million, respectively, after satisfying all the applicable conditions in the indentures.
	Fair Value Disclosures
	The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:
		December 31, 2014								December 31, 2013
		Carrying				Estimated				Carrying			Estimated
		Amount				Fair Value (1)				Amount			Fair Value (1)
	2016 Senior Notes, net of discount	$	1,656,502			$	1,718,621			$	1,651,807		$	1,868,607
	2020 Senior Notes	420,000				428,400				420,000			432,600
	-1	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS
	Terminal Use Agreement
	Sabine Pass Liquefaction, LLC (“Sabine Pass Liquefaction”), a wholly owned subsidiary of Cheniere Partners, obtained approximately 2.0 Bcf/d of regasification capacity under a TUA with us as a result of an assignment in July 2012 by Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, of its rights, title and interest under its TUA with us. Sabine Pass Liquefaction is obligated to make monthly capacity payments to us aggregating approximately $250 million per year, continuing until at least 20 years after Sabine Pass Liquefaction delivers its first commercial cargo at Sabine Pass Liquefaction’s facilities under construction. We entered into a terminal use rights assignment and agreement (“TURA”) with Sabine Pass Liquefaction and Cheniere Investments pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction’s reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to us. Cheniere Investments’ right to use capacity at our LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operations. The percentage of the monthly capacity payments payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the monthly capacity payments payable by Sabine Pass Liquefaction will increase by the amount that Cheniere Investments’ percentage decreases. Cheniere Partners has guaranteed Sabine Pass Liquefaction’s obligations under the TUA and the obligations of Cheniere Investments under the TURA.
	Services Agreements
	We have entered into a long-term operation and maintenance agreement (the “O&M Agreement”) with Cheniere Investments pursuant to which we receive all necessary services required to operate and maintain our LNG receiving terminal. Cheniere Investments provides the services required under the O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. We are required to pay a fixed monthly fee of $130,000 (indexed for inflation) under the O&M Agreement, and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between us and the counterparty at the beginning of each operating year. In addition, we are required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses. Cheniere Investments provides the services required under the Sabine Pass LNG O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	We have entered into a long-term management services agreement (the “MSA”) with Cheniere LNG Terminals, LLC (“Cheniere Terminals”), a wholly owned subsidiary of Cheniere, pursuant to which Cheniere Terminals manages the operation of our LNG receiving terminal, excluding those matters provided for under the O&M Agreement. We are required to pay Cheniere Terminals a monthly fixed fee of $520,000 (indexed for inflation) under the MSA.
	As of December 31, 2014 and 2013, we had $1.9 million and $4.0 million, respectively, of advances to affiliates under the foregoing services agreements. During the years ended December 31, 2014, 2013 and 2012, we recorded general and administrative expense—affiliate of $12.5 million, $13.3 million and $10.8 million, respectively, and we recorded operating and maintenance expense—affiliate of $17.3 million, $25.2 million and $16.0 million respectively, under the foregoing services agreements.
	Agreement to Fund Our Cooperative Endeavor Agreements (“CEAs”)
	In July 2007, we executed CEAs with various Cameron Parish, Louisiana taxing authorities that allow them to collect certain annual property tax payments in 2007 through 2016. This 10-year initiative represents an aggregate commitment of up to $25.0 million, and we will make resources available to the Cameron Parish taxing authorities on an accelerated basis in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for our advance payments of annual ad valorem taxes, Cameron Parish will grant us a dollar for dollar credit against future ad valorem taxes to be levied against our LNG terminal starting in 2019. In September 2007, we entered into an agreement with Cheniere Marketing, pursuant to which Cheniere Marketing would pay us additional TUA revenues equal to any and all amounts payable under the CEAs in exchange for a similar amount of credits against future TUA payments it would owe us under its TUA starting in 2019. In June 2010, Cheniere Marketing assigned its TUA to Cheniere Investments and concurrently entered into a variable capacity rights agreement (“VCRA”), allowing Cheniere Marketing to utilize Cheniere Investments’ capacity under the TUA after the assignment. In July 2012, Cheniere Investments entered into an amended and restated VCRA with Cheniere Marketing in order for Cheniere Investments to utilize during construction of Sabine Pass Liquefaction’s liquefaction project the capacity rights granted under the TURA. Cheniere Marketing will continue to fund the CEAs during the term of the amended and restated VCRA and, in exchange, Cheniere Marketing will receive the benefit of any future credits.
	These advance tax payments were recorded to other non-current assets, and payments from Cheniere Marketing that we utilized to make the ad valorem tax payments were recorded as deferred revenue—affiliate. As of December 31, 2014 and 2013, we had $19.6 million and $17.2 million, respectively, of other non-current assets resulting from ad valorem tax payments and non-current deferred revenue—affiliate resulting from these payments received from Cheniere Marketing.
	Contracts for Sale and Purchase of Natural Gas and LNG
	We are able to sell and purchase natural gas and LNG under agreements with Cheniere Marketing. Under these agreements, we purchase natural gas or LNG from Cheniere Marketing at a sales price equal to the actual purchase cost paid by Cheniere Marketing to suppliers of the natural gas or LNG, plus any third-party costs incurred by Cheniere Marketing in respect of the receipt, purchase and delivery of the natural gas or LNG to our LNG terminal. As a result, we record the purchases of natural gas and LNG from Cheniere Marketing to be utilized as fuel to operate our LNG terminal as operating and maintenance expense. We recorded $3.3 million, $3.3 million and $2.8 million of natural gas purchased from Cheniere Marketing under these agreements as operating and maintenance expense during the years ended December 31, 2014, 2013 and 2012, respectively. We recorded revenues of $0.7 million, $14.7 million and $2.8 million for natural gas sold to Cheniere Marketing under these agreements during the years ended December 31, 2014, 2013 and 2012, respectively.
	LNG Terminal Export Agreement
	In January 2010, we and Cheniere Marketing entered into an LNG Terminal Export Agreement that provides Cheniere Marketing the ability to export LNG from our LNG terminal.  We recorded revenues—affiliate of zero, zero, and $0.3 million pursuant to this agreement in the years ended December 31, 2014, 2013 and 2012, respectively.
	Pipeline Compressor Agreement
	In August 2010, we entered into an agreement with Cheniere Investments, under which Cheniere Investments reimburses us for a portion of the costs of installing, operating and maintaining pipeline compression equipment at our LNG terminal. During the years ended December 31, 2014, 2013 and 2012, we recorded revenues-affiliate from Cheniere Investments of zero, $0.6 million and $0.1 million, respectively.
	Tug Boat Lease Sharing Agreement
	In connection with our tug boat lease, Sabine Pass Tug Services, LLC (“Tug Services”), our wholly owned subsidiary, entered into a tug sharing agreement with a wholly owned subsidiary of Cheniere to provide its LNG cargo vessels with tug boat and marine services at our LNG terminal. Tug Services recorded revenues—affiliate of $2.8 million pursuant to this agreement in each of the years ended December 31, 2014, 2013 and 2012.
	LNG Site Sublease Agreement
	In June 2012, we entered into an agreement with Sabine Pass Liquefaction to sublease a portion of our terminal site for its liquefaction project. The annual sublease payment is $0.5 million. The initial term of the sublease expires on December 31, 2034, with options to renew for five 10-year extensions with similar terms as the initial term. The annual sublease payment will be adjusted for inflation every five years based on a consumer price index, as defined in the sublease agreement. We recognized $0.5 million, $0.5 million and $0.3 million of sublease revenue from Sabine Pass Liquefaction as a credit to operating and maintenance expense—affiliate on our Consolidated Statements of Income for each of the years ended December 31, 2014, 2013 and 2012.
	Cooperation Agreement
	We have entered into an agreement with Sabine Pass Liquefaction to allow Sabine Pass Liquefaction certain rights to access the property and facilities that we own for the purpose of constructing, modifying and operating Sabine Pass Liquefaction’s facilities under construction. In consideration for the access we have given, Sabine Pass Liquefaction has agreed to transfer title to us of certain facilities, equipment and modifications. The term of this agreement is consistent with our TUA described above. As of December 31, 2014, Sabine Pass Liquefaction has conveyed $0.7 million of assets to us under this agreement.

Leases_Notes

Leases (Notes)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Leases	LEASES
	During the years ended December 31, 2014, 2013 and 2012, we recognized rental expense for all operating leases of $9.2 million, $8.8 million and $9.4 million, respectively.
	Future annual minimum lease payments, excluding inflationary adjustments, are as follows (in thousands):
	Year ending December 31,		Lease Payments (2) (3)
	2015		$	9,533
	2016		9,645
	2017		9,764
	2018		2,397
	2019		1,727
	Thereafter (1)		130,714
	Total minimum payments required		$	163,780
	-1	Includes certain lease option renewals as they are reasonably assured.
	-2	Lease payments for our land leases represent our land lease payment obligations and do not take into account the $33.8 million sublease payments we will receive from Sabine Pass Liquefaction, as discussed in Note 8—Related Party Transactions.
	-3	Lease payments for our tug boat lease represent our lease payment obligation and do not take into account the $24.4 million sublease payments we will receive from our customers that effectively offset these lease payment obligations, as discussed below.
	Land Leases
	In January 2005, we exercised our options and entered into three land leases for the site of our LNG terminal. The leases have an initial term of 30 years, with options to renew for six 10-year extensions with similar terms as the initial term. In February 2005, two of the three leases were amended, thereby increasing the total acreage under lease to 853 acres.  In July 2012, we entered into an additional land lease, thereby increasing the total acreage under lease to 883 acres. The annual lease payments are adjusted for inflation every 5 years based on a consumer price index, as defined in the lease agreements. We recognized $1.8 million, $1.8 million and $1.5 million of site lease expense on our Consolidated Statements of Operations in 2014, 2013 and 2012, respectively,
	Tug Boat Lease
	In the second quarter of 2009, we acquired a lease (the “Tug Agreement”) for the use of tug boats and marine services at our LNG terminal as a result of our purchase of Sabine Pass Tug Services, LLC.  The term of the Tug Agreement commenced in January 2008 for a period of 10 years, with an option to renew two additional, consecutive terms of 5 years each.  We have determined that the Tug Agreement contains a lease for the tugs specified in the Tug Agreement.  In addition, we have concluded that the tug lease contained in the Tug Agreement is an operating lease, and as such, the equipment component of the Tug Agreement will be charged to expense over the term of the Tug Agreement as it becomes payable.
	In connection with this lease acquisition, Sabine Pass Tug Services, LLC entered into a tug sharing agreement (the “Tug Sharing Agreement”) with Chevron, Total and a wholly owned subsidiary of Cheniere to provide their LNG cargo vessels with tug boat and marine services at our LNG terminal and effectively offset the cost of the Tug Agreement. The Tug Sharing Agreement provides for each of our customers to pay Sabine Pass Tug Services, LLC an annual service fee that we record as revenue and revenue—affiliate.

Commitments_and_Contingencies_

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES
	LNG TUA Commitments
	We have entered into TUAs with Total, Chevron and Sabine Pass Liquefaction to provide berthing for LNG vessels and for the unloading, storage and regasification of LNG at our LNG terminal. See Note 8—Related Party Transactions for information regarding such agreements.
	Services Agreements
	We have entered into certain services agreements with affiliates. See Note 8—Related Party Transactions for information regarding such agreements.
	Other Commitments
	State Tax Sharing Agreement
	In November 2006, we and Cheniere entered into a state tax sharing agreement. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were computed on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after January 1, 2008.
	Cooperative Endeavor Agreements
	In July 2007, we executed CEAs with various Cameron Parish, Louisiana taxing authorities. See Note 8—Related Party Transactions for information regarding such agreements.
	Legal Proceedings
	We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of December 31, 2014, there were no threatened or pending legal matters that would have a material impact on our consolidated results of operations, financial position or cash flows.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information (Notes)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Year Ended December 31,
		2014		2013		2012
	Cash paid during the year for interest, net of amounts capitalized	$	152,213	$	153,350	$	159,998

Quarterly_Financial_Data_unaud

Quarterly Financial Data (unaudited) (Notes)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Quarterly Financial Data—(in thousands)
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Year ended December 31, 2014:
	Revenues	$	130,734	$	131,040	$	131,001	$	129,932
	Income from operations	104,295		105,890		104,295		102,979
	Net income	64,271		65,690		64,070		62,858
	Year ended December 31, 2013:
	Revenues	$	129,880	$	130,413	$	130,919	$	130,340
	Income from operations	101,576		99,210		102,203		102,115
	Net income	61,854		58,556		61,812		62,071

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Presentation, Policy	Basis of Presentation
	Our Consolidated Financial Statements were prepared in accordance with generally accepted accounting principles in the United States (“GAAP”). Our Consolidated Financial Statements include the accounts of Sabine Pass LNG and its wholly owned subsidiary. All intercompany accounts and transactions have been eliminated in consolidation.
	Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.
Use of Estimates, Policy	Use of Estimates
	The preparation of Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
Fair Value, Policy	Fair Value
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.
	In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates.
	Recurring fair-value measurements are performed for commodity derivatives as disclosed in Note 5—Derivative Instruments. The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Consolidated Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 7—Long-Term Debt, are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments. Non-financial assets and liabilities initially measured at fair value include certain assets and liabilities acquired in a business combination, intangible assets and AROs.
Revenue Recognition, Policy	Revenue Recognition
	LNG regasification capacity reservation fees are recognized as revenue over the term of the TUAs. Advance capacity reservation fees are initially deferred and amortized over a 10-year period as a reduction of a customer’s regasification capacity reservation fees payable under its TUA.  For a discussion of revenue from related parties, please read Note 8—Related Party Transactions.  Under each of these TUAs, Sabine Pass LNG is entitled to retain 2% of LNG delivered for each customer’s account at our LNG terminal, which is recognized as revenue as we perform the services set forth in each customer’s TUA.
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Accounting for LNG Activities, Policy	Accounting for LNG Activities
	Generally, we begin capitalizing the costs of our LNG terminal projects once the individual project meets the following criteria: (i) regulatory approval has been received, (ii) financing for the project is available and (iii) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a project are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to our LNG terminal projects.
	Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as intangible LNG assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed.
	We capitalize interest and other related debt costs during the construction period of our LNG terminal. Upon commencement of operations, capitalized interest, as a component of the total cost, will be amortized over the estimated useful life of the asset.
Property, Plant and Equipment, Policy	Property, Plant and Equipment
	Property, plant and equipment are recorded at cost. Expenditures for construction activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses.
	Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. In performing this test, an undiscounted cash flow analysis is performed at the lowest level for which identifiable cash flows are independent of cash flows from other assets. If the sum of the undiscounted future net cash flows is less than the net book value of the property, an impairment loss is recognized for the excess, if any, of the property’s net book value over its estimated fair value. We have recorded no impairments related to property, plant and equipment for 2014, 2013 or 2012.
Derivative Instruments, Policy	Derivative Instruments
	We use derivative instruments to hedge our exposure to cash-flow variability from commodity price risk.
	Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria, and we elect, the normal purchases and sales exception. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis.
	Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did not have any derivative instruments designated as cash flow hedges as of December 31, 2014 and 2013.
	See Note 5—Derivative Instruments of our Notes to Consolidated Financial Statements for additional details about our derivative instruments.
Concentration of Credit Risk, Policy	Concentration of Credit Risk
	Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date.
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as an other current asset and not netted within the derivative fair value. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments.
	We have entered into certain long-term TUAs with unaffiliated third parties for regasification capacity at our LNG terminal. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective TUAs. We have mitigated this credit risk by securing TUAs for a significant portion of our regasification capacity with creditworthy third-party customers with a minimum Standard & Poor’s rating of AA.
Long-Term Debt, Policy	Long-Term Debt
	Our debt consists of long-term secured debt securities with banks and other lenders.  Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors.
	Debt is recorded on our balance sheet at par value adjusted for unamortized discount or premium. Discounts, premiums and costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Consolidated Statements of Income.
	Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as debt issuance costs on our Consolidated Balance Sheets and are being amortized to interest expense over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off as loss on early extinguishment of debt.
Income Taxes, Policy	Income Taxes
	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Consolidated Financial Statements.
	At December 31, 2014, the tax basis of our assets and liabilities was $460.3 million less than the reported amounts of our assets and liabilities.
	Pursuant to the indentures governing our long-term debt (the “Senior Notes Indentures”), we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The permitted Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the State Tax Sharing Agreement discussed immediately below. The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
	In November 2006, we and Cheniere entered into a state tax sharing agreement. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were computed on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after January 1, 2008.
Asset Retirement Obligations, Policy	Asset Retirement Obligations
	We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our recognition of AROs is described below.
	Based on the real property lease agreements at our LNG terminal, at the expiration of the term of the leases, we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at our LNG terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender our LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero. Therefore, we have not recorded an ARO associated with our LNG terminal.

Property_Plant_and_Equipment_T

Property Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	1,643,018		$	1,642,007
	LNG terminal construction-in-process	27			9
	LNG site and related costs, net	142			149
	Accumulated depreciation	(250,954		)	(208,729		)
	Total LNG terminal costs, net	1,392,233			1,433,436
	Fixed assets
	Machinery and equipment	1,169			1,189
	Computer and office equipment	424			424
	Vehicles	654			599
	Other	697			697
	Accumulated depreciation	(2,734		)	(2,523		)
	Total fixed assets, net	210			386
	Property, plant and equipment, net	$	1,392,443		$	1,433,822
Property, Plant and Equipment Estimated Useful Lives Table	The identifiable components of our LNG terminal with similar estimated useful lives have a depreciable range between 15 and 50 years, as follows:
	Components		Useful life (yrs)
	LNG storage tanks		50
	Marine berth, electrical, facility and roads		35
	Regasification processing equipment (recondensers, vaporization and vents)		30
	Sendout pumps		20
	Others		15-30

Derivative_Instruments_Tables

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Assets and Liabilities	The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of December 31, 2014 and 2013, which are classified as prepaid expenses and other in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		31-Dec-14															31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total			Quoted Prices in Active Markets			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
		(Level 1)															(Level 1)
	LNG Inventory	$	—			$	145			$	—			$	145		$	—		$	—		$	—	$	—
	Derivatives asset
	Fuel Derivatives asset	—				—				—				—			—			27			—		27
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			December 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	145			$	—
	Fuel Derivatives asset	Prepaid expenses and other			—				27
Derivative Gross Presentation on Consolidated Balance Sheets	The following table (in thousands) shows the fair value of our LNG Inventory Derivatives and Fuel Derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized				Gross Amounts Offset in the Consolidated Balance Sheets				Net Amounts Presented in the Consolidated Balance Sheets				Gross Amounts Not Offset in the Consolidated Balance Sheets
	Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
	As of December 31, 2014:
	LNG Inventory Derivatives		$	145			$	132			$	13			$	—		$	—		$	13
	As of December 31, 2013:
	Fuel Derivatives		27				—				27				—			—			27
Derivative gain (loss), net [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Income during the years ended December 31, 2014, 2013 and 2012:
				Year Ended December 31,
				2014				2013				2012
	LNG Inventory Derivatives gain			$	247			$	—			$	—
	Fuel Derivatives gain (loss) (1)			281				182				(622		)
	-1	Excludes settlements of our Fuel Derivatives with Cheniere Marketing for which we have elected the normal purchase normal sale exception from derivative accounting and have recorded as operating and maintenance expense.

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities [Abstract]
Schedule of Accrued Liabilities	As of December 31, 2014 and 2013, accrued liabilities consisted of the following (in thousands):
		December 31,
		2014		2013
	Interest expense and related debt fees	$	14,959	$	14,959
	LNG terminal costs	1,077		1,612
	Other	—		4,582
	Total accrued liabilities	$	16,036	$	21,153

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Instruments	As of December 31, 2014 and 2013, our long-term debt consisted of the following (in thousands):
			December 31,
			2014				2013
	Long-term debt
	2016 Senior Notes		$	1,665,500			$	1,665,500
	2020 Senior Notes		420,000				420,000
	Total long-term debt		2,085,500				2,085,500
	Long-term debt discount
	2016 Senior Notes		(8,998		)		(13,693		)
	Total long-term debt, net		$	2,076,502			$	2,071,807
Schedule of Maturities of Long-term Debt	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2014 (in thousands):
			Payments Due for the Years Ended December 31,
			Total				2015				2016 to 2017			2018 to 2019		Thereafter
	Debt:
	2016 Notes		$	1,665,500			$	—			$	1,665,500		$	—	$	—
	2020 Notes		420,000				—				—			—		420,000
	Debt		$	2,085,500			$	—			$	1,665,500		$	—	$	420,000
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:
		December 31, 2014								December 31, 2013
		Carrying				Estimated				Carrying			Estimated
		Amount				Fair Value (1)				Amount			Fair Value (1)
	2016 Senior Notes, net of discount	$	1,656,502			$	1,718,621			$	1,651,807		$	1,868,607
	2020 Senior Notes	420,000				428,400				420,000			432,600
	-1	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases	Future annual minimum lease payments, excluding inflationary adjustments, are as follows (in thousands):
	Year ending December 31,		Lease Payments (2) (3)
	2015		$	9,533
	2016		9,645
	2017		9,764
	2018		2,397
	2019		1,727
	Thereafter (1)		130,714
	Total minimum payments required		$	163,780
	-1	Includes certain lease option renewals as they are reasonably assured.
	-2	Lease payments for our land leases represent our land lease payment obligations and do not take into account the $33.8 million sublease payments we will receive from Sabine Pass Liquefaction, as discussed in Note 8—Related Party Transactions.
	-3	Lease payments for our tug boat lease represent our lease payment obligation and do not take into account the $24.4 million sublease payments we will receive from our customers that effectively offset these lease payment obligations, as discussed below.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in thousands):
		Year Ended December 31,
		2014		2013		2012
	Cash paid during the year for interest, net of amounts capitalized	$	152,213	$	153,350	$	159,998

Quarterly_Financial_Data_unaud1

Quarterly Financial Data (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Quarterly Financial Data—(in thousands)
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Year ended December 31, 2014:
	Revenues	$	130,734	$	131,040	$	131,001	$	129,932
	Income from operations	104,295		105,890		104,295		102,979
	Net income	64,271		65,690		64,070		62,858
	Year ended December 31, 2013:
	Revenues	$	129,880	$	130,413	$	130,919	$	130,340
	Income from operations	101,576		99,210		102,203		102,115
	Net income	61,854		58,556		61,812		62,071

Organization_and_Nature_of_Ope1

Organization and Nature of Operations (Details)	12 Months Ended
	Dec. 31, 2014
	item
	m3
Sabine Pass LNG terminal [Member]
Organization and nature of operations [Line Items]
Number Of LNG Storage Tanks	5
Storage Capacity, in Bcfe	16.9
Number Of Docks	2
Volume of Vessel, in cubic meters	266,000
Regasification capacity, in Bcf/d	4
Cheniere Energy, Inc. [Member] | Cheniere Energy Partners LP Holdings, LLC [Member]
Organization and nature of operations [Line Items]
Noncontrolling interest ownership percentage by Parent	80.10%
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [Member]
Organization and nature of operations [Line Items]
Limited Partners, ownership percentage	55.90%
Cheniere Energy Partners, LP [Member] | Cheniere Energy Investments, LLC [Member]
Organization and nature of operations [Line Items]
Limited Partners, ownership percentage	100.00%
Cheniere Energy Investments, LLC [Member]
Organization and nature of operations [Line Items]
Limited Partners, ownership percentage	100.00%
Cheniere Energy Investments, LLC [Member] | Sabine Pass LNG-GP, LLC [Member]
Organization and nature of operations [Line Items]
Limited Partners, ownership percentage	100.00%
Cheniere Energy Investments, LLC [Member] | Sabine Pass LNG-LP, LLC [Member]
Organization and nature of operations [Line Items]
Limited Partners, ownership percentage	100.00%

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Advanced capacity reservation fees amortization period	10 years
Retained percentage of LNG delivered	2.00%
Impairments related to property, plant and equipment	$0	$0	$0
Provision for income taxes	0
Entity Not Subject to Income Taxes, Difference in Bases, Amount	460,300,000
Designated as Hedging Instrument [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Derivative instruments designated as cash flow hedges	0	0
Sabine Pass LNG terminal [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligation	0
Sabine Pass LNG terminal [Member] | Maximum [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Property lease term	90 years
Cheniere Energy, Inc. [Member] | Tax Sharing Agreement [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Income Taxes Paid, Net	$0

Restricted_Cash_and_Cash_Equiv1

Restricted Cash and Cash Equivalents (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
	Rate
Restricted Cash and Cash Equivalents Items [Line Items]
Long-term Debt, Gross	2,085,500,000	$2,085,500,000
Current restricted cash and cash equivalents	14,959,000	14,959,000
Non-current restricted cash and cash equivalents	76,106,000	76,106,000
Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt instrument fixed charge coverage ratio	2
2016 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Long-term Debt, Gross	1,665,500,000	1,665,500,000
Debt Instrument, Interest Rate, Stated Percentage	7.50%
2020 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Long-term Debt, Gross	420,000,000	$420,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%

Property_Plant_and_Equipment_D

Property Plant and Equipment (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	1,392,443	$1,433,822
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-250,954	-208,729
Property, plant and equipment, net	1,392,233	1,433,436
LNG terminal costs [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
LNG terminal costs [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,643,018	1,642,007
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	27	9
LNG site and related costs, net [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	142	149
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-2,734	-2,523
Property, plant and equipment, net	210	386
Machinery and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,169	1,189
Computer and Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	424	424
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	654	599
Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	697	$697
LNG storage tanks [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Marine berth, electrical, facility and roads [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	35 years
Regasification processing equipment (recondensers, vaporization, and vents) [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Sendout pumps [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	20 years
Other [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Other [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years

Derivative_Instruments_Fair_Va

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	$145	$0
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	0	0
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	145	0
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	0	0
Fuel Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	0	27
Fuel Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	0	0
Fuel Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	0	27
Fuel Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivatives Assets, at Fair Value, Net	$0	$0

Derivative_Instruments_Fair_Va1

Derivative Instruments - Fair Value by Balance Sheet Location (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	$0
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivatives Asset (Liability), at Fair Value, Net	145	0
Fuel Derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative, Collateral Deposit (Call), Right to Reclaim Cash		0
Fuel Derivatives [Member] | Prepaid Expenses And Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	-100	700
Derivatives Asset (Liability), at Fair Value, Net	$0	$27

Derivative_Instruments_Derivat

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) (Derivative gain (loss), net [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
LNG Inventory Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$247		$0		$0
Fuel Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$281	[1]	$182	[1]	($622)	[1]
[1]	Excludes settlements of our Fuel Derivatives with Cheniere Marketing for which we have elected the normal purchase normal sale exception from derivative accounting and have recorded as operating and maintenance expense.

Derivative_Instruments_Derivat1

Derivative Instruments - Derivatives Gross Presentation on Consolidated Balance Sheets (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$145
Derivative Asset, Gross Amounts Offset in our Balance Sheets	132
Net Amounts Presented in our Balance Sheets	13
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0
Gross Amount Not Offset in our Balance Sheets - Cash Collateral Received (Paid)	0
Derivative Asset, Net Amount	13
Fuel Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		27
Derivative Asset, Gross Amounts Offset in our Balance Sheets		0
Net Amounts Presented in our Balance Sheets		27
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument		0
Gross Amount Not Offset in our Balance Sheets - Cash Collateral Received (Paid)		0
Derivative Asset, Net Amount		$27

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$14,959	$14,959
LNG terminal costs	1,077	1,612
Other	0	4,582
Total accrued liabilities	$16,036	$21,153

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-Term Debt Instruments (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Long-term Debt, Gross	$2,085,500,000	$2,085,500,000
Total long-term debt, net of discount	2,076,502,000	2,071,807,000
2016 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,665,500,000	1,665,500,000
Long-term debt discount	-8,998,000	-13,693,000
2020 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$420,000,000	$420,000,000

LongTerm_Debt_Schedule_of_Matu

Long-Term Debt - Schedule of Maturities of Long-Term Debt (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Total	$2,085,500,000	$2,085,500,000
2015	0
2016 to 2017	1,665,500,000
2018 to 2019	0
Thereafter	420,000,000
2016 Senior Notes [Member]
Debt Instrument [Line Items]
Total	1,665,500,000	1,665,500,000
2015	0
2016 to 2017	1,665,500,000
2018 to 2019	0
Thereafter	0
2020 Senior Notes [Member]
Debt Instrument [Line Items]
Total	420,000,000	420,000,000
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	$420,000,000

LongTerm_Debt_Narrative_Detail

Long-Term Debt - Narrative (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Distributions to limited partner	$346,901,000	$348,938,000	$333,453,000
2016 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,665,500,000
Debt Instrument, Interest Rate, Stated Percentage	7.50%
Debt Instrument, Redemption Price, Percentage	100.00%
Percentage of debt principal additional for redemption	1.00%
Discount rate over Treasury Rate to calculate fair value ratio of redemption price	0.50%
2020 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$420,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Debt redemption period from equity offering closing date	180 days
Minimum [Member] | 2020 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Original Principal Remaining Requirement of Redemption, Percentage	65.00%
Debt Instrument, Redemption, Period One [Member] | 2020 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Price, Percentage	106.50%
Debt Instrument, Redemption, Period One [Member] | Maximum [Member] | 2020 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	35.00%

LongTerm_Debt_Schedule_of_Carr

Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	$2,076,502		$2,071,807
2016 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	1,656,502		1,651,807
2016 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,718,621	[1]	1,868,607	[1]
2020 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	420,000		420,000
2020 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	$428,400	[1]	$432,600	[1]
[1]	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.

Related_Party_Transactions_Ter

Related Party Transactions - Terminal Use Agreement (Details) (Sabine Pass Liquefaction [Member], LNG Terminal Capacity Agreements [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Related Party Transaction [Line Items]
Regasification capacity, in Bcf/d	2
Related Party Transaction, Committed Annual Fee	$250
Related Party Agreement Term	20 years
Maximum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	100.00%
Minimum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	0.00%

Related_Party_Transactions_Ser

Related Party Transactions - Services Agreements (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Advances to affiliate	$1,868,000	$4,025,000
General and administrative expense—affiliate	12,499,000	13,264,000	10,790,000
Operating and maintenance expense, net—affiliate	16,830,000	25,172,000	16,032,000
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate	1,868,000	4,025,000
General and administrative expense—affiliate	12,500,000	13,300,000	10,800,000
Operating and maintenance expense, net—affiliate	17,300,000	25,200,000	16,000,000
Cheniere Energy Investments, LLC [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	130,000
Related Party Transaction, Bonus Percentage Entitled Upon Meeting Certain Criteria	50.00%
Cheniere LNG Terminals, LLC [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	$520,000

Related_Party_Transactions_Coo

Related Party Transactions - Cooperative Endeavor Agreements (Details) (Cheniere Marketing, LLC [Member], Cooperative Endeavor Agreements [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Cheniere Marketing, LLC [Member] | Cooperative Endeavor Agreements [Member]
Related Party Transaction [Line Items]
Tax Initiative Agreement Term	10 years
Aggregate commitment under the Agreement	$25
Due from Related Parties, Noncurrent	$19.60	$17.20

Related_Party_Transactions_Con

Related Party Transactions - Contracts for Sale and Purchase of Natural Gas and LNG (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Revenues—affiliate	$256,760,000	$256,399,000	$255,611,000
Cheniere Marketing, LLC [Member] | Contracts for Sale and Purchase of Natural Gas [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	3,300,000	3,300,000	2,800,000
Revenues—affiliate	$700,000	$14,700,000	$2,800,000

Related_Party_Transactions_Oth

Related Party Transactions - Other Agreements (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Revenues—affiliate	$256,760,000	$256,399,000	$255,611,000
Operating and maintenance expense, net—affiliate	16,830,000	25,172,000	16,032,000
Cheniere Marketing, LLC [Member] | LNG Terminal Export Agreement [Member]
Related Party Transaction [Line Items]
Revenues—affiliate	0	0	300,000
Cheniere Energy Investments, LLC [Member] | Pipeline Compressor Agreement [Member]
Related Party Transaction [Line Items]
Revenues—affiliate	0	600,000	100,000
Sabine Pass Liquefaction [Member]
Related Party Transaction [Line Items]
Property, Plant and Equipment, Transfers and Changes	700,000
Sabine Pass Liquefaction [Member] | LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Annual sublease income	500,000
Number Of Available Lease Extensions	5
Lessee Leasing Arrangements, Operating Leases, Renewal Term	10 years
Review Period for Inflation Adjustment	5 years
Operating and maintenance expense, net—affiliate	500,000	500,000	300,000
Sabine Pass Tug Services, LLC [Member] | Wholly owned subsidiary of Cheniere [Member] | Tug Boat Lease Sharing Agreement [Member]
Related Party Transaction [Line Items]
Revenues—affiliate	$2,800,000	$2,800,000	$2,800,000

Leases_Narrative_Details

Leases - Narrative (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 28, 2005
	lease			acre
	item
	acre
Operating Leased Assets [Line Items]
Operating Leases, Rent Expense	$9.20	$8.80	$9.40
Land [Member]
Operating Leased Assets [Line Items]
Number of Leases	3
Lessee Leasing Arrangements, Operating Leases, Term of Contract	30 years
Number Of Available Lease Extensions	6
Lessee Leasing Arrangements, Operating Leases, Renewal Term	10 years
Number of Amended Land Leases	2
Acreage under lease	883			853
Review Period for Inflation Adjustment	5 years
Operating Leases, Rent Expense, Net	$1.80	$1.80	$1.50
Tug Boat [Member]
Operating Leased Assets [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract	10 years
Number Of Available Lease Extensions	2
Lessee Leasing Arrangements, Operating Leases, Renewal Term	5 years

Leases_Schedule_of_Future_Mini

Leases - Schedule of Future Minimum Rental Payments Due (Details) (USD $)	Dec. 31, 2014
Operating Leased Assets [Line Items]
2015	$9,533,000	[1],[2]
2016	9,645,000	[1],[2]
2017	9,764,000	[1],[2]
2018	2,397,000	[1],[2]
2019	1,727,000	[1],[2]
Thereafter	130,714,000	[1],[2],[3]
Total minimum payments required	163,780,000	[1],[2]
Land [Member] | Sabine Pass Liquefaction [Member]
Operating Leased Assets [Line Items]
Operating Leases, Future Minimum Payments Due, Future Minimum Sublease Rentals	33,800,000
Tug Boat Lease Sharing Agreement [Member]
Operating Leased Assets [Line Items]
Operating Leases, Future Minimum Payments Due, Future Minimum Sublease Rentals	$24,400,000
[1]	Lease payments for our land leases represent our land lease payment obligations and do not take into account the $33.8 million sublease payments we will receive from Sabine Pass Liquefaction, as discussed in
[2]	Lease payments for our tug boat lease represent our lease payment obligation and do not take into account the $24.4 million sublease payments we will receive from our customers that effectively offset these lease payment obligations, as discussed below.
[3]	Includes certain lease option renewals as they are reasonably assured.

Commitments_and_Contingencies_1

Commitments and Contingencies Disclosure (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	0
Tax Sharing Agreement [Member] | Cheniere Energy, Inc. [Member]
Commitments and Contingencies [Line Items]
Income Taxes Paid, Net	$0

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized	$152,213	$153,350	$159,998

Quarterly_Financial_Data_unaud2

Quarterly Financial Data (unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
Revenues	$129,932	$131,001	$131,040	$130,734	$130,340	$130,919	$130,413	$129,880	$522,707	$521,552	$523,884
Income from operations	102,979	104,295	105,890	104,295	102,115	102,203	99,210	101,576	417,459	405,104	427,368
Net income	$62,858	$64,070	$65,690	$64,271	$62,071	$61,812	$58,556	$61,854	$256,889	$244,293	$212,805