Sabine Pass Liquefaction 10-Q 30 Apr 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Central Index Key	1499200
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding	0

Balance_Sheets

Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$0	$0
Restricted cash and cash equivalents	186,295	155,810
Accounts receivable—affiliate	2,074	2,750
Advances to affiliate	12,704	23,969
Prepaid expenses and other	4,457	3,541
Other—affiliate	6,947	153
Total current assets	212,477	186,223
Non-current restricted cash and cash equivalents	1,767,401	457,053
Property, plant and equipment, net	7,523,324	6,962,395
Debt issuance costs, net	202,533	228,913
Non-current derivative assets	472	11,744
Other non-current assets	109,746	99,417
Total assets	9,815,953	7,945,745
Current liabilities
Accounts payable	4,067	5,974
Accrued liabilities	136,573	113,538
Due to affiliates	38,403	13,051
Derivative liabilities	7,252	23,247
Total current liabilities	186,295	155,810
Long-term debt, net	8,516,737	6,517,266
Non-current derivative liabilities	4,762	268
Commitments and contingencies
Member’s equity	1,108,159	1,272,401
Total liabilities and member’s equity	$9,815,953	$7,945,745

Statements_of_Operations

Statements of Operations (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Statement [Abstract]
Revenues	$0	$0
Expenses
Development expense	1,151	3,496
Development expense—affiliate	204	152
General and administrative expense	1,158	1,523
General and administrative expense—affiliate	14,575	19,967
Terminal use agreement maintenance expense (recovery)	17,800	-473
Terminal use agreement maintenance expense—affiliate	35	231
Depreciation expense	406	92
Operating and maintenance expense	2,409	0
Operating and maintenance expense—affiliate	50	0
Total expenses	37,788	24,988
Loss from operations	-37,788	-24,988
Other income (expense)
Interest expense, net	-6,394	0
Loss on early extinguishment of debt	-88,992	0
Derivative loss, net	-36,439	-34,923
Other income	64	71
Total other expense	-131,761	-34,852
Net loss	($169,549)	($59,840)

Statements_of_Members_Equity

Statements of Member's Equity (USD $)	Total	Sabine Pass LNG-LP, LLC [Member]
In Thousands
Members' Equity, beginning of period at Dec. 31, 2014	$1,272,401	$1,272,401
Contributions from Cheniere Partners	5,307	5,307
Net loss	-169,549	-169,549
Member's equity, end of period at Mar. 31, 2015	$1,108,159	$1,108,159

Statements_of_Cash_Flows

Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net loss	($169,549)	($59,840)
Adjustments to reconcile net loss to net cash used in operating activities:
Use of restricted cash and cash equivalents for certain operating activities	53,635	19,292
Depreciation expense	406	92
Non-cash terminal use agreement maintenance expense	16,725	0
Total losses on derivatives, net	36,439	34,914
Net cash used for settlement of derivative instruments	-37,062	-1,926
Loss on extinguishment of debt	88,992	0
Changes in operating assets and liabilities:
Accounts payable	-1,659	0
Accrued liabilities	577	-4
Due to affiliates	23,597	3,406
Advances to affiliate	11,266	4,652
Prepaid expenses and other, net	-656	-3,346
Other—affiliate	-22,711	2,760
Net cash provided by (used in) operating activities	0	0
Cash flows from investing activities
Property, plant and equipment	-529,188	-726,711
Use of restricted cash and cash equivalents for the acquisition of property, plant and equipment	559,801	736,726
Other	-30,613	-10,015
Net cash provided by (used in) investing activities	0	0
Cash flows from financing activities
Proceeds from issuances of long-term debt	2,000,000	0
Contributions from Cheniere Partners	5,307	4,621
Use of (investment) in restricted cash and cash equivalents	-1,955,645	9,336
Debt issuance and deferred financing costs	-49,662	-13,957
Net cash provided (used in) by financing activities	0	0
Net increase (decrease) in cash and cash equivalents	0	0
Cash and cash equivalents—beginning of period	0	0
Cash and cash equivalents—end of period	$0	$0

Basis_of_Presentation_Notes

Basis of Presentation (Notes)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	BASIS OF PRESENTATION
	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall financial position, results of operations or cash flows.
	Results of operations for the three months ended March 31, 2015 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2015.
	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 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 Financial Statements.
	For further information, refer to the Financial Statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2014.
	In June 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on development stage entities. The amendment removed all incremental financial reporting requirements from GAAP for development stage entities. This guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. We adopted this guidance in the quarterly period ended June 30, 2014. Prior to our adoption of this guidance, we were a development stage entity because we devote substantially all of our efforts to establishing a new natural gas liquefaction business and for which planned principal operations have not commenced. The adoption of this guidance did not have a material impact on our financial position, results of operations or cash flows other than the removal of inception-to-date information about statement of operations line items, cash flows and equity transactions.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents (Notes)	3 Months Ended
	Mar. 31, 2015
Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS
	Restricted cash and cash equivalents consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets.
	During 2013, we entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 Liquefaction Credit Facilities”). Under the terms and conditions of the 2013 Liquefaction Credit Facilities, we are required to deposit all cash received into reserve accounts controlled by a collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to our natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”); therefore, these amounts are shown as restricted cash and cash equivalents on our Balance Sheets.
	During 2013, we issued an aggregate principal amount of $2.0 billion, before premium, of 5.625% Senior Secured Notes due 2021 (the “2021 Senior Notes”), $1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 Senior Notes”) and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the “Initial 2023 Senior Notes”). During 2014, we issued an aggregate principal amount of $2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 Senior Notes”) and additional 5.625% Senior Secured Notes due 2023 (the “Additional 2023 Senior Notes” and collectively with the Initial 2023 Senior Notes, the “2023 Senior Notes”) in an aggregate principal amount of $0.5 billion, before premium. During 2015, we issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 Senior Notes” and collectively with the 2021 Senior Notes, the 2022 Senior Notes, the 2023 Senior Notes and the 2024 Senior Notes, the “Senior Notes”). See Note 6—Long-Term Debt for additional details about our long-term debt.
	As of March 31, 2015 and December 31, 2014, we classified $186.3 million and $155.8 million, respectively, as current restricted cash and cash equivalents for the payment of current liabilities, including interest payments, related to the Liquefaction Project and $1,767.4 million and $457.1 million, respectively, as non-current restricted cash and cash equivalents for future Liquefaction Project construction costs.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	3 Months Ended
	Mar. 31, 2015
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):
		March 31,			December 31,
		2015			2014
	LNG terminal costs
	LNG terminal	$	13,171		$	12,821
	LNG terminal construction-in-process	7,506,162			6,946,242
	Accumulated depreciation	(351		)	(260		)
	Total LNG terminal costs, net	7,518,982			6,958,803
	Fixed assets
	Vehicles	1,094			854
	Furniture and fixtures	1,154			1,154
	Machinery and equipment	339			339
	Other	3,116			2,292
	Accumulated depreciation	(1,361		)	(1,047		)
	Total fixed assets, net	4,342			3,592
	Property, plant and equipment, net	$	7,523,324		$	6,962,395

Derivative_Instruments_Notes

Derivative Instruments (Notes)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS
	We have entered into the following derivative instruments that are reported at fair value:
	•	commodity derivatives to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory (“LNG Inventory Derivatives”);
	•	commodity derivatives consisting of natural gas purchase agreements to secure natural gas feedstock for the Liquefaction Project (“Term Gas Supply Derivatives”); and
	•	interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities (“Interest Rate Derivatives”).
	None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Operations.
	The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		31-Mar-15															31-Dec-14
		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 Derivatives asset	$	—			$	352			$	—			$	352		$	—			$	1,071			$	—	$	1,071
	Term Gas Supply Derivatives asset	—				—				342				342			—				—				342		342
	Interest Rate Derivatives liability	—				(11,692		)		—				(11,692		)	—				(12,306		)		—		(12,306		)
	The estimated fair values of our LNG Inventory 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. We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data.
	The fair value of our Term Gas Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of our Term Gas Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of the Term Gas Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a particular Term Gas Supply Derivative contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. Internal fair value models that include contractual pricing with a fixed basis include fixed basis amounts for delivery at locations for which no market currently exists. Internal fair value models also include conditions precedent to the respective long-term natural gas purchase agreements. As of March 31, 2015 and December 31, 2014, the majority of our Term Gas Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. Therefore, our internal fair value models were based on a market price that equated to our own contractual pricing due to: (i) the inactive and unobservable market and (ii) conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of the Term Gas Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed.
	There were no transfers into or out of Level 3 for the three months ended March 31, 2015 and 2014. As all of our Term Gas Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs as of March 31, 2015:
			Net Fair Value Asset		Valuation Technique		Significant Unobservable Input		Significant Unobservable Inputs Range
	Term Gas Supply Derivatives		$342		Income Approach		Basis Spread		$ (0.350) - $0.046
	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.
	Commodity Derivatives
	We recognize all commodity derivative instruments, including our LNG Inventory Derivatives and Term Gas Supply Derivatives (collectively, “Commodity Derivatives”), as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Commodity Derivatives are reported in earnings.
	The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets:
			31-Mar-15												31-Dec-14
			LNG Inventory Derivatives (1)				Term Gas Supply Derivatives				Total Commodity Derivatives				LNG Inventory Derivatives (1)			Term Gas Supply Derivatives				Total Commodity Derivatives
	Balance Sheet Location
	Prepaid expenses and other		$	352			$	190			$	542			$	1,071		$	190			$	1,261
	Non-current derivative assets		—				472				472				—			472				472
	Total derivative assets		352				662				1,014				1,071			662				1,733
	Derivative liabilities		—				(133		)		(133		)		—			(133		)		(133		)
	Non-current derivative liabilities		—				(187		)		(187		)		—			(187		)		(187		)
	Total derivative liabilities		—				(320		)		(320		)		—			(320		)		(320		)
	Net derivative assets		$	352			$	342			$	694			$	1,071		$	342			$	1,413
	-1	Does not include collateral calls of $0.2 million and $1.0 million for such contracts, which are included in prepaid expenses and other current assets in our Balance Sheets as of March 31, 2015 and December 31, 2014, respectively.
	The following table (in thousands) shows the changes in the fair value and settlements of our Commodity Derivatives recorded on our Statements of Operations during the three months ended March 31, 2015 and 2014:
				Three Months Ended March 31,
		Statement of Operation Location		2015				2014
	LNG Inventory Derivatives gain (loss)	Derivative loss, net		$	699			$	(435	)
	Term Gas Supply Derivatives gain (loss) (1)	Operating and maintenance expense		—				—
	(1)    There were no settlements during the reporting period.
	The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position.
	LNG Inventory Derivatives
	Our LNG Inventory Derivatives 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 our LNG Inventory Derivatives activities.
	Term Gas Supply Derivatives
	We have entered into index-based physical natural gas supply contracts to secure natural gas feedstock for the Liquefaction Project. The terms of these contracts range from approximately one to seven years and commence upon the occurrence of conditions precedent, including the date of first commercial operation of specified Trains of the Liquefaction Project. We recognize our Term Gas Supply Derivatives as either assets or liabilities and measure those instruments at fair value.  Changes in the fair value of our Term Gas Supply Derivatives are reported in earnings. As of March 31, 2015, we have secured up to approximately 2,161.9 million MMBtu of natural gas feedstock through long-term natural gas purchase agreements, of which the forward notional natural gas buy position of our Term Gas Supply Derivatives was approximately 1,249.4 million MMBtu.
	Interest Rate Derivatives
	We have entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2013 Liquefaction Credit Facilities. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2013 Liquefaction Credit Facilities.
	In March 2015, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the 2013 Liquefaction Credit Facilities, as discussed in Note 6—Long-Term Debt.
	At March 31, 2015, we had the following Interest Rate Derivatives outstanding:
			Initial Notional Amount		Maximum Notional Amount		Effective Date		Maturity Date		Weighted Average Fixed Interest Rate Paid		Variable Interest Rate Received
	Interest Rate Derivatives		$20.0 million		$691.0 million		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
	The following table (in thousands) shows the fair value of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		March 31, 2015				December 31, 2014
	Interest Rate Derivatives		Non-current derivative assets (Non-current derivative liabilities)		$	(4,573	)		$	11,158
	Interest Rate Derivatives		Derivative liabilities		(7,119		)		(23,194		)
	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three months ended March 31, 2015 and 2014:
		Three Months Ended March 31,
		2015				2014
	Interest Rate Derivatives loss	$	(37,138	)		$	(34,479	)
	Balance Sheet Presentation
	Our Commodity Derivatives and interest rate derivatives are presented on a net basis on our Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized				Gross Amounts Offset in the Balance Sheets				Net Amounts Presented in the Balance Sheets
	Offsetting Derivative Assets (Liabilities)
As of March 31, 2015:
LNG Inventory Derivatives		$	352			$	—			$	352
Term Gas Supply Derivatives		662				—				662
Term Gas Supply Derivatives		(320		)		—				(320		)
Interest Rate Derivatives		(11,692		)		—				(11,692		)
As of December 31, 2014:
LNG Inventory Derivatives		1,071				1,000				71
Term Gas Supply Derivatives		662				—				662
Term Gas Supply Derivatives		(320		)		—				(320		)
Interest Rate Derivatives		11,158				—				11,158
Interest Rate Derivatives		(23,194		)		—				(23,194		)

Accrued_Liabilities_Notes

Accrued Liabilities (Notes)	3 Months Ended
	Mar. 31, 2015
Accrued Liabilities [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES
	As of March 31, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands):
		March 31,		December 31,
		2015		2014
	Interest expense and related debt fees	$	112,628	$	97,785
	LNG liquefaction costs	23,945		15,753
	Total accrued liabilities	$	136,573	$	113,538

LongTerm_Debt_Notes

Long-Term Debt (Notes)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-term Debt	LONG-TERM DEBT
	As of March 31, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands):
			March 31,		December 31,
			2015		2014
	Long-term debt
	2021 Senior Notes		$	2,000,000	$	2,000,000
	2022 Senior Notes		1,000,000		1,000,000
	2023 Senior Notes		1,500,000		1,500,000
	2024 Senior Notes		2,000,000		2,000,000
	2025 Senior Notes		2,000,000		—
	Total long-term debt		8,500,000		6,500,000
	Long-term debt premium
	2021 Senior Notes		9,819		10,177
	2023 Senior Notes		6,918		7,089
	Total long-term debt, net		$	8,516,737	$	6,517,266
	For the three months ended March 31, 2015 and 2014, we incurred $116.1 million and $83.5 million of total interest cost, respectively, of which we capitalized and deferred $109.7 million and $83.5 million, respectively, of interest expense related to the construction of Trains 1 through 4 of the Liquefaction Project.
	Senior Notes
	In February 2013 and April 2013, we issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Senior Notes. In April 2013 and May 2014, we issued an aggregate principal amount of $1.5 billion, before premium, of the 2023 Senior Notes. Borrowings under the 2021 Senior Notes and 2023 Senior Notes accrue interest at a fixed rate of 5.625%. In November 2013, we issued an aggregate principal amount of $1.0 billion of the 2022 Senior Notes, for which borrowings accrue interest at a fixed rate of 6.25%. In May 2014, we issued an aggregate principal amount of $2.0 billion of the 2024 Senior Notes, for which borrowings accrue interest at a fixed rate of 5.75%. In March 2015, we issued an aggregate principal amount of $2.0 billion of the 2025 Senior Notes, for which borrowings accrue interest at a fixed rate of 5.625%. Interest on the Senior Notes is payable semi-annually in arrears.
	The terms of the Senior Notes are governed by a common indenture (the “Indenture”). The Indenture contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our restricted subsidiaries to: incur additional indebtedness; issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness; purchase, redeem or retire capital stock; sell or transfer assets, including capital stock of our restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries; incur liens; enter into transactions with affiliates; consolidate, merge, sell or lease all or substantially all of our assets; and enter into certain LNG sales contracts. Subject to permitted liens, the Senior Notes are secured on a pari passu first-priority basis by a security interest in all of our membership interests and substantially all of our assets. We may not make any distributions until, among other requirements, substantial completion of Trains 1 and 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.
	At any time prior to three months before the respective dates of maturity for each series of the Senior Notes, we may redeem all or part of such series of the Senior Notes at a redemption price equal to the “make-whole” price set forth in the Indenture, plus accrued and unpaid interest, if any, to the date of redemption. We may also, at any time within three months of the respective maturity dates for each series of the Senior Notes, redeem all or part of such series of the Senior Notes at a redemption price equal to 100% of the principal amount of such series of the Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.
	In connection with the closing of the sale of the 2025 Senior Notes, we entered into a Registration Rights Agreement dated March 3, 2015 (the “2025 Liquefaction Registration Rights Agreement”). Under the terms of the 2025 Liquefaction Registration Rights Agreement, we have agreed, and any future guarantors of the 2025 Senior Notes will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective a registration statement with respect to an offer to exchange any and all of the 2025 Senior Notes for a like aggregate principal amount of our debt securities with terms identical in all material respects to the respective 2025 Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), and that are registered under the Securities Act of 1933. We have agreed, and any future guarantors of the 2025 Senior Notes will agree, to use commercially reasonable efforts to cause such registration statement to become effective within 360 days after March 3, 2015. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 2025 Senior Notes. We will be obligated to pay additional interest if we fail to comply with our obligation to register the 2025 Senior Notes within the specified time periods.
	2013 Liquefaction Credit Facilities
	In May 2013, we entered into the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four Trains of the Liquefaction Project. The 2013 Liquefaction Credit Facilities will mature on the earlier of May 28, 2020 or the second anniversary of the completion date of the first four Trains of the Liquefaction Project, as defined in the 2013 Liquefaction Credit Facilities. Borrowings under the 2013 Liquefaction Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. As of March 31, 2015 and December 31, 2014, we had $0.9 billion and $2.7 billion, respectively, of available commitments, and no outstanding borrowings as of both dates, under the 2013 Liquefaction Credit Facilities.
	We made an initial $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent. In November 2013, in conjunction with our issuance of the 2022 Senior Notes, we terminated approximately $885 million of commitments under the 2013 Liquefaction Credit Facilities. In May 2014, we repaid our borrowings under the 2013 Liquefaction Credit Facilities upon the issuance of the Additional 2023 Senior Notes and the 2024 Senior Notes, as well as terminated approximately $2.1 billion of commitments under the 2013 Liquefaction Credit Facilities.
	In March 2015, in conjunction with our issuance of the 2025 Senior Notes, we terminated approximately $1.8 billion of commitments under the 2013 Liquefaction Credit Facilities. This termination resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Liquefaction Credit Facilities of $89.0 million in March 2015.
	Borrowings under the 2013 Liquefaction Credit Facilities accrue interest at a variable rate per annum equal to, at our election, LIBOR or the base rate, plus the applicable margin. The applicable margins for LIBOR loans range from 2.3% to 3.0% prior to the completion of Train 4 and from 2.3% to 3.25% after such completion, depending on the applicable 2013 Liquefaction Credit Facility. Interest on LIBOR loans is due and payable at the end of each LIBOR period. The 2013 Liquefaction Credit Facilities required us to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144 million and provide for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment due quarterly in arrears. Annual administrative fees must also be paid to the agent and the trustee. The principal of the loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing with the earlier of the last day of the first full calendar quarter after the Train 4 completion date, as defined in the 2013 Liquefaction Credit Facilities, or September 30, 2018. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2013 Liquefaction Credit Facilities.
	Under the terms and conditions of the 2013 Liquefaction Credit Facilities, all cash held by us is controlled by a collateral trustee. These funds can only be released by the collateral trustee upon satisfaction of certain terms and conditions related to the use of proceeds, and are classified as restricted on our Balance Sheets.
	The 2013 Liquefaction Credit Facilities contain conditions precedent for any subsequent borrowings, as well as customary affirmative and negative covenants. Our obligations under the 2013 Liquefaction Credit Facilities are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes.
	Under the terms of the 2013 Liquefaction Credit Facilities, we are required to hedge not less than 75% of the variable interest rate exposure of our projected outstanding borrowings, calculated on a weighted average basis in comparison to our anticipated draw of principal. See Note 4—Derivative Instruments.
	Sabine Pass Liquefaction LC Agreement
	In April 2014, we entered into a $325.0 million senior letter of credit and reimbursement agreement (the “Senior LC Agreement”) that we use for the issuance of letters of credit for certain working capital requirements related to the Liquefaction Project. We pay (a) a commitment fee in an amount equal to an annual rate of 0.75% of an amount equal to the unissued portion of letters of credit available pursuant to the Senior LC Agreement and (b) a letter of credit fee equal to an annual rate of 2.5% of the undrawn portion of all letters of credit issued under the Senior LC Agreement. If draws are made upon any letters of credit issued under the Senior LC Agreement, the amount of the draw will be deemed a loan issued to us.  We are required to pay the full amount of this loan on or prior to the business day immediately succeeding the deemed issuance of the loan.  These loans accrue interest at a rate of 2.0% plus the base rate as defined in the Senior LC Agreement. As of March 31, 2015 and December 31, 2014, we had issued letters of credit in an aggregate amount of $72.5 million and $9.5 million, respectively, and as of both March 31, 2015 and December 31, 2014, no draws had been made upon any letters of credit issued under the Senior LC Agreement.
	Fair Value Disclosures
	The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:
			March 31, 2015				December 31, 2014
			Carrying		Estimated		Carrying		Estimated
			Amount		Fair Value		Amount		Fair Value
	2021 Senior Notes, net of premium (1)		$	2,009,819	$	2,024,893	$	2,010,177	$	1,985,050
	2022 Senior Notes (1)		1,000,000		1,030,000		1,000,000		1,020,000
	2023 Senior Notes, net of premium (1)		1,506,918		1,506,918		1,507,089		1,476,947
	2024 Senior Notes (1)		2,000,000		2,000,000		2,000,000		1,970,000
	2025 Senior Notes (1)		2,000,000		1,975,000		—		—
	-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 March 31, 2015 and December 31, 2014, as applicable.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS
	Services Agreements
	We recorded general and administrative expense—affiliate of $14.5 million and $19.9 million and operating and maintenance expense—affiliate of $0.1 million and zero during the three months ended March 31, 2015 and 2014, respectively, under the services agreements listed below.
	Liquefaction O&M Agreement
	We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project. Before the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the Liquefaction Project is operational, the services include all necessary services required to operate and maintain the Liquefaction Project. Before the Liquefaction Project is operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the Liquefaction Project is operational, we will pay in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to such Train. Cheniere Investments provides the services required under the Liquefaction O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	Liquefaction MSA
	We have entered into a management services agreement with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement. The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project. We pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 for services with respect to such Train.
	Terminal Use Agreements
	We have entered into a TUA with Sabine Pass LNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG. We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to Sabine Pass LNG aggregating approximately $250 million per year, continuing until at least 20 years after we deliver our first commercial cargo at our facilities under construction. We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA. In connection with the assignment, we, Cheniere Investments and Sabine Pass LNG also entered into a terminal use rights assignment and agreement (“TURA”) pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to Sabine Pass LNG.  Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. 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 us will increase by the amount that Cheniere Investments’ percentage decreases. Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA.
	In connection with our TUA, we are required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. Terminal use agreement maintenance expense—affiliate represents the amount recorded related to the reimbursement to Sabine Pass LNG of a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal. Our portion of the cost (including affiliate) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. During the three months ended March 31, 2015 and 2014, we recorded expenses of $17.8 million and credits of $0.2 million, respectively, as terminal use agreement maintenance expense (including affiliate) on our Statements of Operations related to this obligation.
	Cheniere Marketing SPA
	Cheniere Marketing has entered into an amended and restated SPA with us to purchase, at Cheniere Marketing’s option, LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG.
	LNG Site Sublease Agreement
	In June 2012, we entered into an agreement with Sabine Pass LNG to sublease a portion of its Sabine Pass LNG terminal site for the 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 5 years based on a consumer price index, as defined in the sublease agreement. We recorded $0.1 million of sublease expense as general and administrative expense—affiliate on our Statements of Operations for each of the three months ended March 31, 2015 and 2014.
	State Tax Sharing Agreement
	In August 2012, we entered into a state tax sharing agreement with Cheniere. 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 calculated 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 August 2012.
	Cooperation Agreement
	We have entered into an agreement with Sabine Pass LNG to allow us certain rights to access the property and facilities that are owned by Sabine Pass LNG for the purpose of constructing, modifying and operating our Liquefaction Project. In consideration for access given to us, we have agreed to transfer to Sabine Pass LNG title of certain facilities, equipment and modifications. The term of this agreement is consistent with our TUA described above. As of both March 31, 2015 and December 31, 2014, we had conveyed $0.7 million of assets to Sabine Pass LNG under this agreement.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information (Notes)	3 Months Ended
	Mar. 31, 2015
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):
		Three Months Ended March 31,
		2015		2014
	Cash paid during the year for interest, net of amounts capitalized and deferred	$	—	$	16,567
	Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	141,656		59,245

Recent_Accounting_Standards_No

Recent Accounting Standards (Notes)	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards	RECENT ACCOUNTING STANDARDS
	In May 2014, the FASB amended its guidance on revenue recognition. The core principle of this amendment is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. This guidance can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our financial position, results of operations and cash flows.
	In August 2014, the FASB issued authoritative guidance that requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. This guidance is effective for annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter, with earlier adoption permitted. The adoption of this guidance is not expected to have an impact on our Financial Statements or related disclosures.
	In April 2015, the FASB issued authoritative guidance that requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance must be adopted retrospectively to each prior reporting period presented and disclosures will be required for a change in accounting principles. Upon adoption of this standard, the balance of long-term debt, net will be reduced by the balance of debt issuance costs, net on our Balance Sheets.

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall financial position, results of operations or cash flows.
Income Tax, Policy	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 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 Financial Statements.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2015
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):
		March 31,			December 31,
		2015			2014
	LNG terminal costs
	LNG terminal	$	13,171		$	12,821
	LNG terminal construction-in-process	7,506,162			6,946,242
	Accumulated depreciation	(351		)	(260		)
	Total LNG terminal costs, net	7,518,982			6,958,803
	Fixed assets
	Vehicles	1,094			854
	Furniture and fixtures	1,154			1,154
	Machinery and equipment	339			339
	Other	3,116			2,292
	Accumulated depreciation	(1,361		)	(1,047		)
	Total fixed assets, net	4,342			3,592
	Property, plant and equipment, net	$	7,523,324		$	6,962,395

Derivative_Instruments_Tables

Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
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 instruments that are required to be measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		31-Mar-15															31-Dec-14
		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 Derivatives asset	$	—			$	352			$	—			$	352		$	—			$	1,071			$	—	$	1,071
	Term Gas Supply Derivatives asset	—				—				342				342			—				—				342		342
	Interest Rate Derivatives liability	—				(11,692		)		—				(11,692		)	—				(12,306		)		—		(12,306		)
Fair Value Inputs Assets Quantitative Information	The following table (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs as of March 31, 2015:
			Net Fair Value Asset		Valuation Technique		Significant Unobservable Input		Significant Unobservable Inputs Range
	Term Gas Supply Derivatives		$342		Income Approach		Basis Spread		$ (0.350) - $0.046
Derivative Net Presentation on Balance Sheets	The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized				Gross Amounts Offset in the Balance Sheets				Net Amounts Presented in the Balance Sheets
	Offsetting Derivative Assets (Liabilities)
	As of March 31, 2015:
	LNG Inventory Derivatives		$	352			$	—			$	352
	Term Gas Supply Derivatives		662				—				662
	Term Gas Supply Derivatives		(320		)		—				(320		)
	Interest Rate Derivatives		(11,692		)		—				(11,692		)
	As of December 31, 2014:
	LNG Inventory Derivatives		1,071				1,000				71
	Term Gas Supply Derivatives		662				—				662
	Term Gas Supply Derivatives		(320		)		—				(320		)
	Interest Rate Derivatives		11,158				—				11,158
	Interest Rate Derivatives		(23,194		)		—				(23,194		)
Commodity Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets:
			31-Mar-15												31-Dec-14
			LNG Inventory Derivatives (1)				Term Gas Supply Derivatives				Total Commodity Derivatives				LNG Inventory Derivatives (1)			Term Gas Supply Derivatives				Total Commodity Derivatives
	Balance Sheet Location
	Prepaid expenses and other		$	352			$	190			$	542			$	1,071		$	190			$	1,261
	Non-current derivative assets		—				472				472				—			472				472
	Total derivative assets		352				662				1,014				1,071			662				1,733
	Derivative liabilities		—				(133		)		(133		)		—			(133		)		(133		)
	Non-current derivative liabilities		—				(187		)		(187		)		—			(187		)		(187		)
	Total derivative liabilities		—				(320		)		(320		)		—			(320		)		(320		)
	Net derivative assets		$	352			$	342			$	694			$	1,071		$	342			$	1,413
	-1	Does not include collateral calls of $0.2 million and $1.0 million for such contracts, which are included in prepaid expenses and other current assets in our Balance Sheets as of March 31, 2015 and December 31, 2014, respectively.
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our Commodity Derivatives recorded on our Statements of Operations during the three months ended March 31, 2015 and 2014:
				Three Months Ended March 31,
		Statement of Operation Location		2015				2014
	LNG Inventory Derivatives gain (loss)	Derivative loss, net		$	699			$	(435	)
	Term Gas Supply Derivatives gain (loss) (1)	Operating and maintenance expense		—				—
	(1)    There were no settlements during the reporting period.
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions	At March 31, 2015, we had the following Interest Rate Derivatives outstanding:
			Initial Notional Amount		Maximum Notional Amount		Effective Date		Maturity Date		Weighted Average Fixed Interest Rate Paid		Variable Interest Rate Received
	Interest Rate Derivatives		$20.0 million		$691.0 million		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		March 31, 2015				December 31, 2014
	Interest Rate Derivatives		Non-current derivative assets (Non-current derivative liabilities)		$	(4,573	)		$	11,158
	Interest Rate Derivatives		Derivative liabilities		(7,119		)		(23,194		)
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three months ended March 31, 2015 and 2014:
		Three Months Ended March 31,
		2015				2014
	Interest Rate Derivatives loss	$	(37,138	)		$	(34,479	)

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2015
Accrued Liabilities [Abstract]
Schedule of Accrued Liabilities	As of March 31, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands):
		March 31,		December 31,
		2015		2014
	Interest expense and related debt fees	$	112,628	$	97,785
	LNG liquefaction costs	23,945		15,753
	Total accrued liabilities	$	136,573	$	113,538

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	As of March 31, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands):
			March 31,		December 31,
			2015		2014
	Long-term debt
	2021 Senior Notes		$	2,000,000	$	2,000,000
	2022 Senior Notes		1,000,000		1,000,000
	2023 Senior Notes		1,500,000		1,500,000
	2024 Senior Notes		2,000,000		2,000,000
	2025 Senior Notes		2,000,000		—
	Total long-term debt		8,500,000		6,500,000
	Long-term debt premium
	2021 Senior Notes		9,819		10,177
	2023 Senior Notes		6,918		7,089
	Total long-term debt, net		$	8,516,737	$	6,517,266
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:
			March 31, 2015				December 31, 2014
			Carrying		Estimated		Carrying		Estimated
			Amount		Fair Value		Amount		Fair Value
	2021 Senior Notes, net of premium (1)		$	2,009,819	$	2,024,893	$	2,010,177	$	1,985,050
	2022 Senior Notes (1)		1,000,000		1,030,000		1,000,000		1,020,000
	2023 Senior Notes, net of premium (1)		1,506,918		1,506,918		1,507,089		1,476,947
	2024 Senior Notes (1)		2,000,000		2,000,000		2,000,000		1,970,000
	2025 Senior Notes (1)		2,000,000		1,975,000		—		—
	-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 March 31, 2015 and December 31, 2014, as applicable.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2015
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in thousands):
		Three Months Ended March 31,
		2015		2014
	Cash paid during the year for interest, net of amounts capitalized and deferred	$	—	$	16,567
	Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	141,656		59,245

Restricted_Cash_and_Cash_Equiv1

Restricted Cash and Cash Equivalents (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Mar. 31, 2015	31-May-13	Dec. 31, 2013
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash and cash equivalents	$155,810,000	$186,295,000
Non-current restricted cash and cash equivalents	457,053,000	1,767,401,000
2013 Liquefaction Credit Facilities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			5,900,000,000
2021 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.63%
2022 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%
2023 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		1,500,000,000		1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.63%
Debt Instrument, Increase (Decrease), Net	500,000,000
2024 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%
2025 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.63%
Payment of Liabilities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash and cash equivalents	155,810,000	186,295,000
Construction Activities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current restricted cash and cash equivalents	$457,053,000	$1,767,401,000

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$7,523,324	$6,962,395
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-351	-260
Property, plant and equipment, net	7,518,982	6,958,803
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,171	12,821
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,506,162	6,946,242
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-1,361	-1,047
Property, plant and equipment, net	4,342	3,592
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,094	854
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,154	1,154
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	339	339
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$3,116	$2,292

Derivative_Instruments_Narrati

Derivative Instruments - Narrative (Details) (USD $)	3 Months Ended		1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	31-May-14	Nov. 30, 2013
	MMBTU
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Asset Transfers Into Level 3	$0	$0
Asset Transfers out of Level 3	0	0
Energy Units Secured Through Long-Term Purchase Agreements, in MMBtu	2,161,900,000		2,161,900,000
2013 Liquefaction Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Increase (Decrease)			-1,800,000,000	-2,100,000,000	-885,000,000
Term Gas Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount, in MMBtu	1,249,400,000		1,249,400,000
Term Gas Supply Derivatives [Member] | Minimum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	1 year
Term Gas Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	7 years
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net			($34,700,000)

Derivative_Instruments_Fair_Va

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$352	$1,071
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), 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]
Derivative Assets (Liabilities), at Fair Value, Net	352	1,071
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342	342
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342	342
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-11,692	-12,306
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-11,692	-12,306
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$0	$0

Derivative_Instruments_Derivat

Derivative Instruments Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) (Term Gas Supply Derivatives [Member], USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$342,000	$342,000
Valuation Technique	Income Approach
Significant Unobservable Input	Basis Spread
Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	-0.35
Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$0.05

Derivative_Instruments_Fair_Va1

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Non-current derivative assets	$472,000		$11,744,000
Derivative liabilities	-7,252,000		-23,247,000
Non-current derivative liabilities	-4,762,000		-268,000
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	1,014,000		1,733,000
Total derivative liabilities	-320,000		-320,000
Net derivative assets	694,000		1,413,000
Commodity Contract [Member] | Prepaid expenses and other [Member]
Derivatives, Fair Value [Line Items]
Prepaid expenses and other	542,000		1,261,000
Commodity Contract [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	472,000		472,000
Commodity Contract [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	-133,000		-133,000
Commodity Contract [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	-187,000		-187,000
LNG Inventory Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	352,000	[1]	1,071,000	[1]
Total derivative liabilities	0	[1]	0	[1]
Net derivative assets	352,000	[1]	1,071,000	[1]
LNG Inventory Derivatives [Member] | Prepaid expenses and other [Member]
Derivatives, Fair Value [Line Items]
Prepaid expenses and other	352,000	[1]	1,071,000	[1]
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	-200,000		-1,000,000
LNG Inventory Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	0	[1]	0	[1]
LNG Inventory Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0	[1]	0	[1]
LNG Inventory Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	0	[1]	0	[1]
Term Gas Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	662,000		662,000
Total derivative liabilities	-320,000		-320,000
Net derivative assets	342,000		342,000
Term Gas Supply Derivatives [Member] | Prepaid expenses and other [Member]
Derivatives, Fair Value [Line Items]
Prepaid expenses and other	190,000		190,000
Term Gas Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	472,000		472,000
Term Gas Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	-133,000		-133,000
Term Gas Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	-187,000		-187,000
Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Assets			11,158,000
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities	-7,119,000		-23,194,000
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities	($4,573,000)
[1]	Does not include collateral calls of $0.2 million and $1.0 million for such contracts, which are included in prepaid expenses and other current assets in our Balance Sheets as of March 31, 2015 and December 31, 2014, respectively.

Derivative_Instruments_Derivat1

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) (USD $)	3 Months Ended				1 Months Ended
	Mar. 31, 2015		Mar. 31, 2014		Mar. 31, 2015
LNG Inventory Derivatives [Member] | Derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$699,000		($435,000)
Term Gas Supply Derivatives [Member] | Operating and maintenance expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	[1]	0	[1]
Settlements during the period	0		0
Interest Rate Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net					-34,700,000
Interest Rate Derivatives [Member] | Derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	($37,138,000)		($34,479,000)
[1]	There were no settlements during the reporting period.

Derivative_Instruments_Schedul

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) (Interest Rate Derivatives [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Derivative [Line Items]
Notional Amount	$20
Effective Date	14-Aug-12
Maturity Date	31-Jul-19
Weighted Average Fixed Interest Rate Paid	1.98%
Variable Interest Rate Received	One-month LIBOR
Maximum [Member]
Derivative [Line Items]
Notional Amount	$691

Derivative_Instruments_Derivat2

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$352	$1,071
Derivative Asset, Gross Amounts Offset in the Balance Sheets	0	1,000
Net Amounts Presented in our Balance Sheets	352	71
Term Gas Supply Derivatives - Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	-320	-320
Derivative Liability, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	-320	-320
Term Gas Supply Derivatives - Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	662	662
Derivative Asset, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	662	662
Interest Rate Derivatives - Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	-11,692	-23,194
Derivative Liability, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	-11,692	-23,194
Interest Rate Derivatives - Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		11,158
Derivative Asset, Gross Amounts Offset in the Balance Sheets		0
Net Amounts Presented in our Balance Sheets		$11,158

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$112,628	$97,785
LNG liquefaction costs	23,945	15,753
Total accrued liabilities	$136,573	$113,538

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Gross	$8,500,000,000		$6,500,000,000
Total long-term debt, net	8,516,737,000		6,517,266,000
Interest costs incurred	116,100,000	83,500,000
Interest costs capitalized and deferred	109,700,000	83,500,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,000,000,000		2,000,000,000
Debt Instrument, Unamortized Premium	9,819,000		10,177,000
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,000,000,000		1,000,000,000
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,500,000,000		1,500,000,000
Debt Instrument, Unamortized Premium	6,918,000		7,089,000
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,000,000,000		2,000,000,000
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$2,000,000,000		$0

LongTerm_Debt_Senior_Notes_Det

Long-Term Debt - Senior Notes (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2013
	Rate
Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Fixed Charge, Coverage Ratio Period	12 months
Debt Instrument, Fixed Charge, Coverage Ratio	1.25
Debt Instrument, Redemption Price, Percentage	100.00%
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,500,000,000	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%

LongTerm_Debt_2013_Liquefactio

Long-Term Debt - 2013 Liquefaction Credit Facilities (Details) (USD $)	3 Months Ended		1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	31-May-14	Nov. 30, 2013	Jun. 30, 2013	Dec. 31, 2014	31-May-13
Line of Credit Facility [Line Items]
Long-term Debt, Gross	$8,500,000,000		$8,500,000,000				$6,500,000,000
Loss on extinguishment of debt	88,992,000	0
2013 Liquefaction Credit Facilities [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								5,900,000,000
Line of Credit Facility, Remaining Borrowing Capacity	900,000,000		900,000,000				2,700,000,000
Long-term Debt, Gross	0		0				0
Proceeds from (Repayments of) Lines of Credit						100,000,000
Line of Credit Facility, Increase (Decrease)			-1,800,000,000	-2,100,000,000	-885,000,000
Loss on extinguishment of debt			89,000,000
Debt Instrument, Description of Variable Rate Basis	LIBOR
Debt Instrument, Fee Amount								$144,000,000
Commitment Fee Percentage of Applicable Margin	40.00%
Line of Credit Facility, Amortization Period	18 years
2013 Liquefaction Credit Facilities [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives	75.00%		75.00%
2013 Liquefaction Credit Facilities [Member] | Minimum [Member] | Operations [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
2013 Liquefaction Credit Facilities [Member] | Minimum [Member] | Construction [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
2013 Liquefaction Credit Facilities [Member] | Maximum [Member] | Operations [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.25%
2013 Liquefaction Credit Facilities [Member] | Maximum [Member] | Construction [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.00%

LongTerm_Debt_Liquefaction_LC_

Long-Term Debt - Liquefaction LC Agreement (Details) (Liquefaction LC Agreement [Member], USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Apr. 30, 2014
Line of Credit Facility [Line Items]
Letter of Credit and Reimbursement Agreement			$325,000,000
Letter of Credit, Basis Spread over Base Rate	2.00%
Letters of Credit, Outstanding, Amount	72,500,000	9,500,000
Letters of Credit, Drawn, Amount	$0	$0
Unissued Portion [Member]
Line of Credit Facility [Line Items]
Letter of Credit, Commitment Fee Percentage	0.75%
Portion issued and not drawn [Member]
Line of Credit Facility [Line Items]
Letter of Credit, Commitment Fee Percentage	2.50%

LongTerm_Debt_Schedule_of_Carr

Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	$8,516,737		$6,517,266
Carrying Amount [Member] | 2021 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	2,009,819		2,010,177
Carrying Amount [Member] | 2022 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	1,000,000		1,000,000
Carrying Amount [Member] | 2023 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	1,506,918		1,507,089
Carrying Amount [Member] | 2024 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	2,000,000		2,000,000
Carrying Amount [Member] | 2025 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	2,000,000		0
Estimated Fair Value [Member] | 2021 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	2,024,893	[1]	1,985,050	[1]
Estimated Fair Value [Member] | 2022 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,030,000	[1]	1,020,000	[1]
Estimated Fair Value [Member] | 2023 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,506,918	[1]	1,476,947	[1]
Estimated Fair Value [Member] | 2024 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	2,000,000	[1]	1,970,000	[1]
Estimated Fair Value [Member] | 2025 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	$1,975,000	[1]	$0	[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 March 31, 2015 and December 31, 2014, as applicable.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Related Party Transaction [Line Items]
General and administrative expense—affiliate	$14,575,000	$19,967,000
Operating and maintenance expense—affiliate	50,000	0
Service Agreements [Member]
Related Party Transaction [Line Items]
General and administrative expense—affiliate	14,500,000	19,900,000
Operating and maintenance expense—affiliate	100,000	0
Cheniere Energy Investments, LLC [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	0.60%
Related Party Transaction, Committed Monthly Fee	83,333
Cheniere LNG Terminals, LLC [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	2.40%
Related Party Transaction, Committed Monthly Fee	541,667
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member]
Related Party Transaction [Line Items]
Regasification capacity, in Bcf/d	2
Related Party Transaction, Committed Annual Fee	250,000,000
Related Party Agreement Term	20 years
Portion of storage capacity reserved	41.00%
Terminal Use Agreement Maintenance Expense Including Affiliate	17,800,000	200,000
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	100.00%
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	0.00%
Sabine Pass LNG, LP [Member] | LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment	500,000
Number Of Available Lease Extensions	5
Term of available extension	10 years
Review Period for Inflation Adjustment	5 years
Operating Leases, Rent Expense, Net	100,000	100,000
Sabine Pass LNG, LP [Member] | Cooperation Agreement [Member]
Related Party Transaction [Line Items]
Property, Plant and Equipment, Transfers and Changes	700,000	700,000
Cheniere Marketing, LLC [Member] | LNG Sale and Purchase Agreement [Member]
Related Party Transaction [Line Items]
Incremental LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
Incremental LNG Volume, Purchase Price Per MMBtu	3
Cheniere Energy, Inc. [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net	$0

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized and deferred	$0	$16,567
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$141,656	$59,245