Sabine Pass Liquefaction 10-Q 30 Oct 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014
Document and Entity Information [Abstract]	'
Entity Registrant Name	'Sabine Pass Liquefaction, LLC
Entity Central Index Key	'0001499200
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Non-accelerated Filer
Document Type	'10-Q
Document Period End Date	30-Sep-14
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'Q3
Amendment Flag	'false
Entity Common Stock, Shares Outstanding	0

Balance_Sheets

Balance Sheets (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$0	$0
Restricted cash and cash equivalents	312,435	192,144
Accounts receivable—affiliate	1,036	1,167
Advances to affiliate	7,819	9,430
Prepaid expenses and other	2,114	4,390
Other—affiliate	4,342	121
Total current assets	327,746	207,252
Non-current restricted cash and cash equivalents	1,050,946	867,590
Property, plant and equipment, net	6,447,511	4,412,580
Debt issuance costs, net	236,906	296,040
Non-current derivative assets	32,161	98,123
Other	66,006	60,387
Total assets	8,161,276	5,941,972
Current liabilities	'	'
Accounts payable	6,354	8,067
Accrued liabilities	259,021	144,575
Due to affiliates	29,958	26,019
Derivative liabilities	17,102	13,484
Total current liabilities	312,435	192,145
Long-term debt, net	6,517,787	4,111,562
Commitments and contingencies	'	'
Members' Equity	'	'
Member’s equity	1,331,054	1,638,265
Total liabilities and member’s equity	$8,161,276	$5,941,972

Statements_of_Operations

Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues	'	'	'	'
Revenues	$0	$0	$0	$0
Expenses	'	'	'	'
Development expense	1,383	0	8,671	2,102
Development expense—affiliate	329	0	723	877
General and administrative expense	513	889	3,859	2,569
General and administrative expense—affiliate	17,215	35,293	52,644	73,216
Terminal use agreement maintenance expense	10,064	14,406	24,497	27,308
Terminal use agreement maintenance expense—affiliate	169	205	506	205
Depreciation expense	310	49	671	134
Operating and maintenance expense	2,353	0	4,388	0
Operating and maintenance expense—affiliate	29	0	34	0
Total expenses	32,365	50,842	95,993	106,411
Loss from operations	-32,365	-50,842	-95,993	-106,411
Other income (expense)	'	'	'	'
Interest expense, net	-16,773	0	-16,773	-12,239
Loss on early extinguishment of debt	0	0	-114,335	-80,510
Derivative gain (loss), net	5,508	-22,280	-89,670	55,710
Other income (expense)	71	86	-105	660
Total other expense	-11,194	-22,194	-220,883	-36,379
Net loss	($43,559)	($73,036)	($316,876)	($142,790)

Statements_of_Comprehensive_Lo

Statements of Comprehensive Loss (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net loss	($43,559)	($73,036)	($316,876)	($142,790)
Other comprehensive income	'	'	'	'
Loss on settlements of interest rate cash flow hedges retained in other comprehensive income	0	0	0	-30
Change in fair value of interest rate cash flow hedges	0	0	0	21,297
Losses reclassified into earnings as a result of discontinuance of cash flow hedge accounting	0	0	0	5,973
Total other comprehensive income	0	0	0	27,240
Comprehensive loss	($43,559)	($73,036)	($316,876)	($115,550)

Statements_of_Members_Equity

Statements of Member's Equity (USD $)	Total	Sabine Pass LNG-LP, LLC [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
In Thousands
Members' Equity, beginning of period at Dec. 31, 2013	$1,638,265	$1,638,265	$0
Contributions from Cheniere Partners	10,410	10,410	0
Non-cash contributions to limited partner	-745	-745	0
Net loss	-316,876	-316,876	0
Member's equity, end of period at Sep. 30, 2014	$1,331,054	$1,331,054	$0

Statements_of_Cash_Flows

Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Cash flows from operating activities	'	'
Net loss	($316,876)	($142,790)
Adjustments to reconcile net loss to net cash used in operating activities:	'	'
Use of restricted cash and cash equivalents for certain operating activities	119,196	114,840
Depreciation	671	134
Non-cash terminal use agreement maintenance expense	23,505	27,540
Total (gains) losses on derivatives, net	89,670	-55,710
Net cash from settlement of derivative instruments	-20,245	326
Loss on extinguishment of debt	114,335	80,510
Changes in operating assets and liabilities:	'	'
LNG inventory	-24,499	-14,566
Accounts payable	5,033	10
Accrued liabilities	1,018	-100
Due to affiliates	9,639	8,972
Advances to affiliate	1,612	-17,683
Prepaid expenses and other	-3,188	-211
Other—affiliates	129	-1,272
Net cash provided by (used in) operating activities	0	0
Cash flows from investing activities	'	'
Property, plant and equipment	-1,888,589	-2,413,946
Use of restricted cash and cash equivalents for the acquisition of property, plant and equipment	1,900,776	2,428,283
Other	-12,187	-14,337
Net cash provided by (used in) investing activities	0	0
Cash flows from financing activities	'	'
Proceeds from issuances of long-term debt	2,584,500	3,112,500
Repayments of long-term debt	-177,000	-100,000
Contributions from Cheniere Partners	10,410	328,266
Investment in restricted cash and cash equivalents	-2,323,620	-3,070,302
Debt issuance and deferred financing costs	-94,290	-270,464
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)	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	BASIS OF PRESENTATION
	The accompanying unaudited Financial Statements of Sabine Pass Liquefaction, LLC have been prepared in accordance with generally accepted accounting principles in the United States of America (“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 and nine months ended September 30, 2014 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2014.
	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 Energy Partners, L.P. (“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, 2013.
	In June 2014, the Financial Accounting Standards Board (“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 income statement line items, cash flows, and equity transactions.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents (Notes)	9 Months Ended
	Sep. 30, 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 and have been presented separately from cash and cash equivalents on our Balance Sheets.
	In July 2012, we entered into a construction/term loan facility in an amount up to $3.6 billion (the “2012 Liquefaction Credit Facility”). During 2013, we entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 Liquefaction Credit Facilities”), which amended and restated the 2012 Liquefaction Credit Facility. See Note 5—“Long-Term Debt.” Under the terms and conditions of the 2012 Liquefaction Credit Facility we were required, and under the 2013 Liquefaction Credit Facilities we are required, to deposit all cash received into reserve accounts controlled by a collateral trustee. Therefore, all of our cash and cash equivalents 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 “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 collectively with the 2021 Senior Notes, the 2022 Senior Notes and the 2023 Senior Notes, the “Senior Notes”), and additional 2023 Senior Notes (the “Additional 2023 Senior Notes”) in an aggregate principal amount of $0.5 billion, before premium.
	As of September 30, 2014 and December 31, 2013, we classified $312.4 million and $192.1 million, respectively, as current restricted cash and cash equivalents for the payment of current liabilities related to the natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) and $1,050.9 million and $867.6 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)	9 Months Ended
	Sep. 30, 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):
		September 30,			December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	12,821		$	98
	LNG terminal construction-in-process	6,431,912			4,412,077
	Accumulated depreciation	(168		)	—
	Total LNG terminal costs, net	6,444,565			4,412,175
	Fixed assets
	Vehicles	854			309
	Furniture and fixtures	1,154			10
	Machinery and equipment	339			301
	Other	1,441			125
	Accumulated depreciation	(842		)	(340		)
	Total fixed assets, net	2,946			405
	Property, plant and equipment, net	$	6,447,511		$	4,412,580

Accrued_Liabilities_Notes

Accrued Liabilities (Notes)	9 Months Ended
	Sep. 30, 2014
Accrued Liabilities [Abstract]	'
Accrued Liabilities	'
	ACCRUED LIABILITIES
	As of September 30, 2014 and December 31, 2013, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		September 30,		December 31,
		2014		2013
	Interest expense and related debt fees	$	102,281	$	65,153
	LNG liquefaction costs	156,740		79,422
	Total accrued liabilities	259,021		144,575
	Accrued liabilities—affiliate	29,623		25,559
	Total accrued liabilities (including affiliate)	$	288,644	$	170,134

LongTerm_Debt_Notes

Long-Term Debt (Notes)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Long-term Debt	'
	LONG-TERM DEBT
	As of September 30, 2014 and December 31, 2013, our long-term debt consisted of the following (in thousands):
		September 30,		December 31,
		2014		2013
	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		1,000,000
	2024 Senior Notes	2,000,000		—
	2013 Liquefaction Credit Facilities	—		100,000
	Total long-term, debt	6,500,000		4,100,000
	Long-term debt premium
	2021 Senior Notes	10,530		11,562
	2023 Senior Notes	7,257		—
	Total long-term debt, net	$	6,517,787	$	4,111,562
	For the three months ended September 30, 2014 and 2013, we incurred $109.6 million and $58.7 million of total interest cost, respectively, of which we capitalized and deferred $92.8 million and $58.7 million, respectively, of interest expense related to the construction of natural gas liquefaction trains (“Trains”) 1 through 4 of the Liquefaction Project. For the nine months ended September 30, 2014 and 2013, we incurred $288.3 million and $165.6 million of total interest cost, respectively, of which we capitalized and deferred $271.5 million and $153.4 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 bear 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. Borrowings under the 2022 Senior Notes bear 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. Borrowings under the 2024 Senior Notes bear interest at a fixed rate of 5.75%. 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 or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or 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 November 1, 2020, with respect to the 2021 Senior Notes; December 15, 2021, with respect to the 2022 Senior Notes; January 15, 2023, with respect to the 2023 Senior Notes; or February 15, 2024, with respect to the 2024 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 on or after November 1, 2020, with respect to the 2021 Senior Notes; December 15, 2021, with respect to the 2022 Senior Notes; January 15, 2023, with respect to the 2023 Senior Notes; or February 15, 2024, with respect to the 2024 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 issuance of the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes, we entered into registration rights agreements (the “Liquefaction Registration Rights Agreements”). Under the Liquefaction Registration Rights Agreements, we have agreed to use commercially reasonable efforts to file with the Securities and Exchange Commission (“SEC”) and cause to become effective registration statements relating to offers to exchange the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes for like aggregate principal amounts of SEC-registered notes with terms identical in all material respects to the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes (other than with respect to restrictions on transfer or to any increase in annual interest rate), respectively, within 360 days after November 25, 2013 and May 20, 2014, as applicable. Under specified circumstances, we may be required to file shelf registration statements to cover resales of the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes. If we fail to satisfy these obligations, we may be required to pay additional interest to holders of the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes under certain circumstances. On August 26, 2014, Sabine Pass Liquefaction filed a registration statement with the SEC related to the exchange offers with respect to the 2022 Senior Notes, the 2024 Senior Notes and the Additional 2023 Senior Notes, which became effective on October 22, 2014.
	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. We made an initial $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent, and 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 of September 30, 2014 and December 31, 2013, we had $2.7 billion and $4.9 billion, respectively, of available commitments under the 2013 Liquefaction Credit Facilities.
	Borrowings under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at our election, the London Interbank Offered Rate (“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 agent. These funds can only be released by the collateral agent 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 6—“Financial Instruments.”
	In November 2013, we issued the 2022 Senior Notes, and a portion of the available commitments under the 2013 Liquefaction Credit Facilities was terminated. Net proceeds from the offering of approximately $978 million are being used to pay a portion of the capital costs in connection with the construction of the first four Trains of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2013 Liquefaction Credit Facilities. The 2022 Senior Notes are pari passu in right of payment with all of our existing and future senior debt. In conjunction with our issuance of the 2022 Notes in November 2013, we have terminated approximately $885 million 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 $43.3 million in November 2013.
	In May 2014, we issued the 2024 Senior Notes and the Additional 2023 Senior Notes, and a portion of the available commitments under the 2013 Liquefaction Credit Facilities was terminated. Net proceeds from the offering of approximately $2.5 billion were used to repay our outstanding indebtedness under the 2013 Liquefaction Credit Facilities, and the remaining proceeds are being used to pay a portion of the capital costs in connection with the construction of the first four Trains of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2013 Liquefaction Credit Facilities. The 2024 Senior Notes and the Additional 2023 Senior Notes are pari passu in right of payment with all of our existing and future senior debt. As a result of our issuance of the 2024 Senior Notes and the Additional 2023 Senior Notes in May 2014, we terminated approximately $2.1 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 $114.3 million in May 2014.
	2012 Liquefaction Credit Facility
	In July 2012, we entered into the 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 and 2 of the Liquefaction Project. Borrowings under the 2012 Liquefaction Credit Facility were based on LIBOR plus 3.50% during construction and LIBOR plus 3.75% during operations. We were also required to pay commitment fees on the undrawn amount. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.
	Under the terms of the 2012 Liquefaction Credit Facility, we were 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 6—“Financial Instruments.”
	In February 2013, we issued the 2021 Senior Notes to refinance a portion of the 2012 Liquefaction Credit Facility, and a portion of available commitments under the 2012 Liquefaction Credit Facility were suspended. In April 2013, we issued an aggregate principal amount of $500.0 million of additional 2021 Senior Notes and $1.0 billion of 2023 Senior Notes. In conjunction with these issuances, approximately $1.4 billion of commitments under the 2012 Liquefaction Credit Facility were terminated. The termination of these commitments in April 2013 and the amendment and restatement of the 2012 Liquefaction Credit Facility with the 2013 Liquefaction Credit Facilities in May 2013 resulted in a write-off of debt issuance costs associated with the 2012 Liquefaction Credit Facility of zero and $80.5 million in the three and nine months ended September 30, 2013, respectively.
	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 intend to use for the issuance of letters of credit for certain working capital requirements related to the Liquefaction Project. We will 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 bear interest at a rate of 2.0% plus the base rate as defined in the Senior LC Agreement. As of September 30, 2014, we had issued letters of credit in an aggregate amount of $9.5 million and no draws had been made upon any letters of credit issued under the Senior LC Agreement.

Financial_Instruments_Notes

Financial Instruments (Notes)	9 Months Ended
	Sep. 30, 2014
Financial Instruments, Owned, at Fair Value [Abstract]	'
Financial Instruments	'
	FINANCIAL INSTRUMENTS
	Derivative Instruments
	Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly owned subsidiary of Cheniere Energy, Inc. (“Cheniere”), has entered into the following derivative instruments, on our behalf, 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 feed stock 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”).
	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 September 30, 2014 and December 31, 2013, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		30-Sep-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 Derivatives asset (liability)	$	—			$	(210	)		$	—			$	(210	)	$	—		$	(156	)		$	—	$	(156	)
	Interest Rate Derivatives asset	—				15,059				—				15,059			—			84,639				—		84,639
	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. Internal fair value models for our index-priced Term Gas Supply Derivatives 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 for our index-priced Term Gas Supply Derivatives also include conditions precedent to the respective long-term natural gas purchase agreements. As of September 30, 2014, our Term Gas Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow and our internal fair value models were based on a market price that equated to our own contractual pricing due to the inactive and unobservable market as well as the conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward.
	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.
	LNG Inventory Derivatives
	We recognize our LNG Inventory Derivatives as either assets or liabilities and measure those instruments at fair value. The changes in the fair value of our LNG Inventory Derivatives are reported in earnings.
	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 LNG Inventory Derivatives are in an asset position. 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. We had collateral deposits of $0.3 million and $0.2 million for such contracts, which have not been reflected in the derivative fair value tables, included in the other current assets balance as of September 30, 2014 and December 31, 2013, respectively.
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives on our Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			September 30, 2014				December 31, 2013
	LNG Inventory Derivatives liability	Prepaid expenses and other			$	(210	)		$	—
	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives recorded in derivative gain (loss), net on our Statements of Operations during the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2014				2013				2014				2013
	LNG Inventory Derivatives gain (loss)	$	129			$	201			$	(448	)		$	976
	Natural Gas Purchase Agreements
	We have entered into index-based physical natural gas supply contracts to secure natural gas feed stock 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 natural gas purchase agreements 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 September 30, 2014, our Term Gas Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow and our internal fair value models were based on a market price that equated to our own contractual pricing due to the inactive and unobservable market as well as the conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. As a result, we estimated the fair value of our Term Gas Supply Derivatives to be zero as of September 30, 2014. During the three and nine months ended September 30, 2014, there were no settlements or changes in the fair value of our Term Gas Supply Derivatives recorded in operating and maintenance expense on our Statements of Operations. As of September 30, 2014, the forward notional natural gas buy position of our Term Gas Supply Derivatives was approximately 2,161,000,000 MMBtu.
	Interest Rate Derivatives
	In August 2012 and June 2013, we entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, respectively. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2013 Liquefaction Credit Facilities.
	We designated the Interest Rate Derivatives entered into in August 2012 as hedging instruments which was required in order to qualify for cash flow hedge accounting. As a result of this cash flow hedge designation, we recognized the Interest Rate Derivatives entered into in August 2012 as an asset or liability at fair value and reflected changes in fair value through other comprehensive income in our Statements of Comprehensive Loss.
	Any hedge ineffectiveness associated with the Interest Rate Derivatives entered into in August 2012 was recorded immediately as derivative gain (loss) in our Statements of Operations.  The realized gain (loss) on the Interest Rate Derivatives entered into in August 2012 was recorded as an (increase) decrease in interest expense on our Statements of Operations to the extent not capitalized as part of the Liquefaction Project. The effective portion of the gains or losses on our Interest Rate Derivatives entered into in August 2012 recorded in other comprehensive income would have been reclassified to earnings as interest payments on the 2012 Liquefaction Credit Facility impact earnings. In addition, amounts recorded in other comprehensive income are also reclassified into earnings if it becomes probable that the hedged forecasted transaction will not occur.
	We did not elect to designate the Interest Rate Derivatives entered into in June 2013 as cash flow hedging instruments, and changes in fair value are recorded as derivative gain (loss) within our Statements of Operations.
	During the first quarter of 2013, we determined that it was no longer probable that the forecasted variable interest payments on the 2012 Liquefaction Credit Facility would occur in the time period originally specified based on the continued development of our financing strategy for the Liquefaction Project, and, in particular, the Senior Notes described in Note 5—“Long-Term Debt.” As a result, all of the Interest Rate Derivatives entered into in August 2012 were no longer effective hedges, and the remaining portion of hedge relationships that were designated cash flow hedges as of December 31, 2012, were de-designated as of February 1, 2013. For de-designated cash flow hedges, changes in fair value prior to their de-designation date are recorded as other comprehensive income (loss) within our Balance Sheets, and changes in fair value subsequent to their de-designation date are recorded as derivative gain (loss) within our Statements of Operations.
	In June 2013, we concluded that the hedged forecasted transactions associated with the Interest Rate Derivatives entered into in connection with the 2012 Liquefaction Credit Facility had become probable of not occurring based on the issuances of the Senior Notes, the closing of the 2013 Liquefaction Credit Facilities, the additional Interest Rate Derivatives executed in June 2013, and our intention to continue to issue fixed rate debt to refinance the 2013 Liquefaction Credit Facilities. As a result, the amount remaining in accumulated other comprehensive income (“AOCI”) pertaining to the previously designated Interest Rate Derivatives was reclassified out of AOCI and into income. We have presented the reclassification of unrealized losses from AOCI into income and the changes in fair value and settlements subsequent to the reclassification date separate from interest expense as derivative gain (loss), net in our Statements of Operations.
	In May 2014, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $9.3 million within our Statements of Operations in conjunction with the termination of approximately $2.1 billion of commitments under the 2013 Liquefaction Credit Facilities as discussed in Note 5—“Long-Term Debt.”
	At September 30, 2014, 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 - Not Designated		$20.0 million		$2.5 billion		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		September 30, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	32,161			$	98,123
	Interest Rate Derivatives - Not Designated		Derivative liabilities		(17,102		)		(13,484		)
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income (“OCI”) and AOCI during the nine months ended September 30, 2014 and 2013:
		Gain (Loss) in Other Comprehensive Income								Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)							Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
		2014				2013				2014				2013			2014			2013
	Interest Rate Derivatives - Designated	$	—			$	21,297			$	—			$	—		$	—		$	(5,806	)
	Interest Rate Derivatives - Settlements	—				(30		)		—				—			—			(167		)
	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Statements of Operations during the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2014				2013				2014				2013
	Interest Rate Derivatives - Not Designated	$	5,379			$	(22,481	)		$	(89,222	)		$	60,707
	Balance Sheet Presentation
	Our commodity 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				Gross Amounts Not Offset in the Balance Sheets
	Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
	As of September 30, 2014:
	LNG Inventory Derivatives		$	(210	)		$	(210	)		$	—			$	—		$	—		$	—
	Interest Rate Derivatives - Not Designated		15,059				—				15,059				—			—			15,059
	As of December 31, 2013:
	LNG Inventory Derivatives		(156		)		(156		)		—				—			—			—
Interest Rate Derivatives - Not Designated		98,123				—				98,123				—			—			98,123
Interest Rate Derivatives - Not Designated		(13,484		)		—				(13,484		)		—			—			(13,484		)
Other Financial Instruments
The estimated fair value of our other financial instruments, including those financial instruments for which the fair value option was not elected, are set forth in the table below.  The carrying amounts reported on our Balance Sheets for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, interest receivable and accounts payable approximate fair value due to their short-term nature.
The following table (in thousands) shows the carrying amount and estimated fair value of our other financial instruments:
		September 30, 2014								December 31, 2013
		Carrying				Estimated				Carrying				Estimated
		Amount				Fair Value				Amount				Fair Value
2021 Senior Notes, net of premium (1)		$	2,010,530			$	2,045,714			$	2,011,562			$	1,961,273
2022 Senior Notes (1)		1,000,000				1,042,500				1,000,000				982,500
2023 Senior Notes, net of premium (1)		1,507,257				1,507,257				1,000,000				935,000
2024 Senior Notes (1)		2,000,000				2,010,000				—				—
2013 Liquefaction Credit Facilities (2)		—				—				100,000				100,000
-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 September 30, 2014 and December 31, 2013, as applicable.
-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	Services Agreements
	We recorded general and administrative expense—affiliate of $17.1 million and $35.2 million during the three months ended September 30, 2014 and 2013, respectively, and $52.3 million and $72.9 million during the nine months ended September 30, 2014 and 2013, respectively, under the services agreements listed below.
	Sabine Pass Liquefaction O&M Agreement
	We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Energy Investments, LLC (“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 facilities. Cheniere Investments provides the services required under the Liquefaction O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. Before the liquefaction facilities are 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 facilities are operational, the services include all necessary services required to operate and maintain the liquefaction facilities. Before the liquefaction facilities are 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 facilities are 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.
	During the second quarter of 2014, four lawsuits were filed in the Court of Chancery of the State of Delaware (the “Court”) against Cheniere and/or certain of its present and former officers and directors that challenge the manner in which abstentions were treated in connection with the stockholder vote on Amendment No. 1 to the Cheniere Energy, Inc. 2011 Incentive Plan (“Amendment No. 1”), pursuant to which, among other things, the number of shares of common stock available for issuance under the Cheniere Energy, Inc. 2011 Incentive Plan (the “2011 Plan”) was increased from 10 million to 35 million shares. The lawsuits contend that abstentions should have been counted as “no” votes in tabulating the outcome of the vote and that the stockholders did not approve Amendment No. 1 when abstentions are counted as such. The lawsuits further contend that portions of the Amended and Restated Bylaws of Cheniere Energy, Inc. adopted on April 3, 2014 are invalid and that certain disclosures relating to these matters made by Cheniere are misleading. The lawsuits assert claims for breach of contract and breach of fiduciary duty (both on a class and a derivative basis) and claims for unjust enrichment (on a derivative basis). The lawsuits seek, among other things, a declaration that the February 1, 2013 stockholder vote on Amendment No. 1 is void, disgorgement of all compensation distributed as a result of Amendment No. 1, voiding the awards made from the shares reserved pursuant to Amendment No. 1 and monetary damages. On June 16, 2014, Cheniere filed a verified application with the Court pursuant to 8 Del. C. § 205 (the “Section 205 Action”) in which it asks the Court to declare valid the issuance, pursuant to the 2011 Plan, of the 25 million additional shares of common stock of Cheniere covered by Amendment No. 1, whether occurring in the past or the future. On June 27, 2014, the Court entered an order staying the stockholder litigation pending resolution of the Section 205 Action. On July 11, 2014, Cheniere filed a memorandum of law in support of its motion for judgment on Application I asserted in the Section 205 Action (that it correctly tabulated votes in connection with the stockholder vote on Amendment No. 1). On July 25, 2014, certain of the plaintiffs in the lawsuits (who have been given permission to intervene in the Section 205 Action) filed a brief in opposition to Cheniere’s motion for judgment on Application I in the Section 205 Action. Briefing on these issues was completed on August 20, 2014, and the Court held a hearing on the motion on August 26, 2014.
	The parties to the above-referenced lawsuits and the Section 205 Action have reached a memorandum of understanding (the “MOU”), subject to its terms and conditions, including receipt, among other things, of Court approval, to resolve the litigation. The MOU contemplates the dismissal with prejudice of the stockholder actions and the Section 205 Action and a release being granted to the defendants by the plaintiffs and a class of Cheniere’s stockholders. As part of the contemplated settlement: (i) the parties will request that the Court validate, pursuant to 8 Del. C. § 205, all awards made pursuant to Amendment No. 1 (whether vested or unvested) and declare that recipients of such awards are entitled to keep their awarded shares; (ii) except with respect to the unawarded shares discussed below, Cheniere will not seek stockholder approval for any stock-based compensation prior to January 1, 2017, such that no stock based compensation will be awarded to company executives, directors or consultants other than to the extent stockholders have already approved such compensation or such compensation was approved pursuant to 8 Del. C. § 205 (notwithstanding the foregoing, authorized stock (unissued or treasury) may be used to compensate new employees and a cash pay award (bonus, incentive, etc.) tied to the performance of Cheniere’s stock shall not constitute stock-based compensation); (iii) all compensation-related votes through September 17, 2022 will be subject to a majority of the shares present and entitled to vote standard (pursuant to which abstentions will be counted as the functional equivalent of “no” votes and broker non-votes will not be considered in determining the outcome of the resolution, but will be counted for purposes of establishing a quorum); and (iv) the Compensation Committee will be comprised exclusively of independent directors as defined by the NYSE MKT (or the rules of the primary exchange on which Cheniere’s common stock is listed in the future). With respect to the shares authorized pursuant to Amendment No. 1, but not awarded: (i) Cheniere will not award any of these shares unless the issuance of the shares is approved by a new stockholder vote; (ii) no earlier than 90-days after Court approval of the settlement, Cheniere may submit the issue of the unawarded shares to a stockholder vote; and (iii) if stockholders approve issuance of the unawarded shares, no more than 1 million of those shares may be awarded to Mr. Souki.
	Consummation of the settlement is subject to several conditions including (i) completion of confirmatory discovery; (ii) agreement on an appropriate stipulation of settlement and such other documentation as may be required to obtain final approval of the settlement; and (iii) approval of all aspects of the settlement. The MOU requires the settlement to be submitted for Court approval within 60 days from the date of the MOU. Cheniere has also agreed that plaintiffs’ counsel is entitled to a fee in connection with the resolution of the Stockholder Actions, which fee will be paid by defendants, their insurance carrier, Cheniere or any combination thereof. The amount of the fee has not yet been determined.
	The outcome of this litigation may impact the amount of operating expenses that Cheniere charged to us under the Liquefaction O&M Agreement. Given the stage of this ongoing litigation, Cheniere currently cannot reasonably estimate a range of potential loss, if any, related to this matter.
	Sabine Liquefaction MSA
	We have entered into a management services agreement with a wholly owned subsidiary of Cheniere pursuant to which such subsidiary manages the construction and operation of the liquefaction facilities, 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 facilities. 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 terminal use agreement (“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 September 30, 2014 and 2013, we recorded $10.2 million and $14.6 million, respectively, and during the nine months ended September 30, 2014 and 2013, we recorded $25.0 million and $27.5 million, respectively, as terminal use agreement maintenance expense (including affiliate) on our Statements of Operations related to this obligation.
	Cheniere Marketing Sale and Purchase Agreement (“SPA”)
	Cheniere Marketing has entered into an amended and restated SPA with us (the “Cheniere Marketing SPA”) 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 five 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 September 30, 2014 and 2013 and $0.4 million for each of the nine months ended September 30, 2014 and 2013.
	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 title to Sabine Pass LNG of certain facilities, equipment and modifications. The term of this agreement is consistent with our TUA described above. As of September 30, 2014, we have conveyed $0.7 million of assets to Sabine Pass LNG under this agreement.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information (Notes)	9 Months Ended
	Sep. 30, 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):
		Nine Months Ended September 30,
		2014		2013
	LNG terminal costs funded with accounts payable and accrued liabilities (including affiliates)	$	270,761	$	84,566

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	The accompanying unaudited Financial Statements of Sabine Pass Liquefaction, LLC have been prepared in accordance with generally accepted accounting principles in the United States of America (“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 and nine months ended September 30, 2014 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2014.
	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 Energy Partners, L.P. (“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, 2013.
	In June 2014, the Financial Accounting Standards Board (“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 income statement line items, cash flows, and equity transactions.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 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):
		September 30,			December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	12,821		$	98
	LNG terminal construction-in-process	6,431,912			4,412,077
	Accumulated depreciation	(168		)	—
	Total LNG terminal costs, net	6,444,565			4,412,175
	Fixed assets
	Vehicles	854			309
	Furniture and fixtures	1,154			10
	Machinery and equipment	339			301
	Other	1,441			125
	Accumulated depreciation	(842		)	(340		)
	Total fixed assets, net	2,946			405
	Property, plant and equipment, net	$	6,447,511		$	4,412,580

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2014
Accrued Liabilities [Abstract]	'
Schedule of Accrued Liabilities	'
	As of September 30, 2014 and December 31, 2013, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		September 30,		December 31,
		2014		2013
	Interest expense and related debt fees	$	102,281	$	65,153
	LNG liquefaction costs	156,740		79,422
	Total accrued liabilities	259,021		144,575
	Accrued liabilities—affiliate	29,623		25,559
	Total accrued liabilities (including affiliate)	$	288,644	$	170,134

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments	'
	As of September 30, 2014 and December 31, 2013, our long-term debt consisted of the following (in thousands):
		September 30,		December 31,
		2014		2013
	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		1,000,000
	2024 Senior Notes	2,000,000		—
	2013 Liquefaction Credit Facilities	—		100,000
	Total long-term, debt	6,500,000		4,100,000
	Long-term debt premium
	2021 Senior Notes	10,530		11,562
	2023 Senior Notes	7,257		—
	Total long-term debt, net	$	6,517,787	$	4,111,562

Financial_Instruments_Tables

Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2014 and December 31, 2013, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		30-Sep-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 Derivatives asset (liability)	$	—			$	(210	)		$	—			$	(210	)	$	—		$	(156	)		$	—	$	(156	)
	Interest Rate Derivatives asset	—				15,059				—				15,059			—			84,639				—		84,639
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 on our Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			September 30, 2014				December 31, 2013
	LNG Inventory Derivatives liability	Prepaid expenses and other			$	(210	)		$	—
Schedule of Notional Amounts of Outstanding Derivative Positions	'
	At September 30, 2014, 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 - Not Designated		$20.0 million		$2.5 billion		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	'
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income (“OCI”) and AOCI during the nine months ended September 30, 2014 and 2013:
		Gain (Loss) in Other Comprehensive Income								Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)							Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
		2014				2013				2014				2013			2014			2013
	Interest Rate Derivatives - Designated	$	—			$	21,297			$	—			$	—		$	—		$	(5,806	)
	Interest Rate Derivatives - Settlements	—				(30		)		—				—			—			(167		)
Derivative Gross 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				Gross Amounts Not Offset in the Balance Sheets
	Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
	As of September 30, 2014:
	LNG Inventory Derivatives		$	(210	)		$	(210	)		$	—			$	—		$	—		$	—
	Interest Rate Derivatives - Not Designated		15,059				—				15,059				—			—			15,059
	As of December 31, 2013:
	LNG Inventory Derivatives		(156		)		(156		)		—				—			—			—
	Interest Rate Derivatives - Not Designated		98,123				—				98,123				—			—			98,123
	Interest Rate Derivatives - Not Designated		(13,484		)		—				(13,484		)		—			—			(13,484		)
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 other financial instruments:
			September 30, 2014								December 31, 2013
			Carrying				Estimated				Carrying				Estimated
			Amount				Fair Value				Amount				Fair Value
	2021 Senior Notes, net of premium (1)		$	2,010,530			$	2,045,714			$	2,011,562			$	1,961,273
	2022 Senior Notes (1)		1,000,000				1,042,500				1,000,000				982,500
	2023 Senior Notes, net of premium (1)		1,507,257				1,507,257				1,000,000				935,000
	2024 Senior Notes (1)		2,000,000				2,010,000				—				—
	2013 Liquefaction Credit Facilities (2)		—				—				100,000				100,000
	-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 September 30, 2014 and December 31, 2013, as applicable.
	-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.
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 recorded in derivative gain (loss), net on our Statements of Operations during the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2014				2013				2014				2013
	LNG Inventory Derivatives gain (loss)	$	129			$	201			$	(448	)		$	976
Interest Rate 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 of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		September 30, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	32,161			$	98,123
	Interest Rate Derivatives - Not Designated		Derivative liabilities		(17,102		)		(13,484		)
Interest Rate Contract [Member] | 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 Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Statements of Operations during the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2014				2013				2014				2013
	Interest Rate Derivatives - Not Designated	$	5,379			$	(22,481	)		$	(89,222	)		$	60,707

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures	'
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Nine Months Ended September 30,
		2014		2013
	LNG terminal costs funded with accounts payable and accrued liabilities (including affiliates)	$	270,761	$	84,566

Restricted_Cash_and_Cash_Equiv1

Restricted Cash and Cash Equivalents (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Jul. 31, 2012

Apr. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Apr. 30, 2013

Sep. 30, 2014

31-May-13

Sep. 30, 2014

Dec. 31, 2013

2012 Liquefaction Credit Facility [Member]

2021 Sabine Pass Liquefaction Senior Notes [Member]

2021 Sabine Pass Liquefaction Senior Notes [Member]

2022 Senior Notes [Member]

2023 Senior Notes [Member]

2023 Senior Notes [Member]

2023 Senior Notes [Member]

2024 Senior Notes [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

Construction Activities [Member]

Construction Activities [Member]

Restricted Cash and Cash Equivalents Items [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

$3,600,000,000

'

'

'

'

'

'

'

$5,900,000,000

'

'

Debt Instrument, Face Amount

'

'

'

'

2,000,000,000

1,000,000,000

1,500,000,000

1,000,000,000

1,000,000,000

2,000,000,000

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

5.63%

6.25%

5.63%

5.63%

'

5.75%

'

'

'

Debt Instrument, Increase (Decrease), Net

'

'

'

500,000,000

'

'

500,000,000

'

'

'

'

'

'

Current restricted cash and cash equivalents

312,435,000

192,144,000

'

'

'

'

'

'

'

'

'

312,435,000

192,144,000

Non-current restricted cash and cash equivalents

$1,050,946,000

$867,590,000

'

'

'

'

'

'

'

'

'

$1,050,946,000

$867,590,000

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, net	$6,447,511	$4,412,580
LNG terminal costs [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation	-168	0
Property, plant and equipment, net	6,444,565	4,412,175
LNG terminal [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	12,821	98
LNG terminal construction-in-process [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	6,431,912	4,412,077
Fixed assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation	-842	-340
Property, plant and equipment, net	2,946	405
Vehicles [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	854	309
Furniture and Fixtures [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	1,154	10
Machinery and Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	339	301
Other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	$1,441	$125

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities [Abstract]	'	'
Interest expense and related debt fees	$102,281	$65,153
LNG liquefaction costs	156,740	79,422
Total accrued liabilities	259,021	144,575
Accrued liabilities—affiliate	29,623	25,559
Total accrued liabilities (including affiliate)	$288,644	$170,134

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	$6,500,000,000	'	$6,500,000,000	'	$4,100,000,000
Total long-term debt, net	6,517,787,000	'	6,517,787,000	'	4,111,562,000
Interest costs incurred	109,600,000	58,700,000	288,300,000	165,600,000	'
Interest costs capitalized and deferred	92,800,000	58,700,000	271,500,000	153,400,000	'
2021 Senior Notes [Member]	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	2,000,000,000	'	2,000,000,000	'	2,000,000,000
Debt Instrument, Unamortized Premium	10,530,000	'	10,530,000	'	11,562,000
2022 Senior Notes [Member]	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	1,000,000,000	'	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	'	1,000,000,000
Debt Instrument, Unamortized Premium	7,257,000	'	7,257,000	'	0
2024 Senior Notes [Member]	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	2,000,000,000	'	2,000,000,000	'	0
2013 Sabine Pass Liquefaction Credit Facilities [Member]	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Long-term Debt, Gross	$0	'	$0	'	$100,000,000

LongTerm_Debt_Senior_Notes_Det

Long-Term Debt - Senior Notes (Details) (USD $)	9 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Dec. 31, 2013	Apr. 30, 2013	Sep. 30, 2014
	Senior Notes [Member]	2021 Senior Notes [Member]	2022 Senior Notes [Member]	2023 Senior Notes [Member]	2023 Senior Notes [Member]	2023 Senior Notes [Member]	2024 Senior Notes [Member]
	Rate
Debt Instrument [Line Items]	'	'	'	'	'	'	'
Debt Instrument, Face Amount	'	$2,000,000,000	$1,000,000,000	$1,500,000,000	$1,000,000,000	$1,000,000,000	$2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	'	5.63%	6.25%	5.63%	5.63%	'	5.75%
Debt Instrument, Fixed Charge, Coverage Ratio Period	'12 months	'	'	'	'	'	'
Debt Instrument, Fixed Charge, Coverage Ratio	1.25	'	'	'	'	'	'
Debt Instrument, Redemption Price, Percentage	100.00%	'	'	'	'	'	'
Period Allowed After Debt Issuance For SEC Registration	'	'	'360 days	'	'	'	'

LongTerm_Debt_2013_Liquefactio

Long-Term Debt - 2013 Liquefaction Credit Facilities (Details) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

9 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

31-May-14

Nov. 30, 2013

Jun. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

31-May-13

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Nov. 30, 2013

31-May-14

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2013 Sabine Pass Liquefaction Credit Facilities [Member]

2022 Senior Notes [Member]

2024 And Additional 2023 Sabine Pass Liquefaction Senior Notes [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Operations [Member]

Construction [Member]

Operations [Member]

Construction [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

$5,900,000,000

'

'

'

'

'

'

'

Proceeds from (Repayments of) Lines of Credit

'

'

-177,000,000

-100,000,000

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

'

'

'

'

'

'

'

2,700,000,000

4,900,000,000

'

'

'

'

'

'

'

'

Debt Instrument, Description of Variable Rate Basis

'

'

'

'

'

'

'

'LIBOR

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

2.30%

2.30%

3.25%

3.00%

'

'

Debt Instrument, Fee Amount

'

'

'

'

'

'

'

144,000,000

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Commitment Fee Percentage

'

'

'

'

'

'

'

40.00%

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amortization Period

'

'

'

'

'

'

'

'18 years

'

'

'

'

'

'

'

'

'

Percentage of Debt Hedged by Interest Rate Derivatives

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

Proceeds from issuances of long-term debt

'

'

2,584,500,000

3,112,500,000

'

'

'

'

'

'

'

'

'

'

'

978,000,000

2,500,000,000

Line of Credit Facility, Increase (Decrease)

'

'

'

'

-2,100,000,000

-885,000,000

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

$0

$0

$114,335,000

$80,510,000

'

'

'

'

'

'

'

'

'

'

'

$43,300,000

$114,300,000

LongTerm_Debt_2012_Liquefactio

Long-Term Debt - 2012 Liquefaction Credit Facility (Details) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

31-May-13

Apr. 30, 2013

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Apr. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Apr. 30, 2013

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2012 Liquefaction Credit Facility [Member]

2021 Sabine Pass Liquefaction Senior Notes [Member]

2021 Sabine Pass Liquefaction Senior Notes [Member]

2023 Sabine Pass Liquefaction Senior Notes [Member]

2023 Sabine Pass Liquefaction Senior Notes [Member]

2023 Sabine Pass Liquefaction Senior Notes [Member]

Construction [Member]

Operations [Member]

Minimum [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Description of Variable Rate Basis

'

'

'

'

'

'

'

'LIBOR

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

3.50%

3.75%

'

'

'

'

'

'

Proceeds from (Repayments of) Lines of Credit

'

'

$177,000,000

$100,000,000

$100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of Debt Hedged by Interest Rate Derivatives

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

Debt Instrument, Increase (Decrease), Net

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

500,000,000

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000,000

1,500,000,000

1,000,000,000

1,000,000,000

Line of Credit Facility, Increase (Decrease)

'

'

'

'

'

-1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

Loss on early extinguishment of debt

$0

$0

$114,335,000

$80,510,000

'

'

$0

'

$80,500,000

'

'

'

'

'

'

'

'

LongTerm_Debt_Liquefaction_LC_

Long-Term Debt - Liquefaction LC Agreement (Details) (Liquefaction LC Agreement [Member], USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Line of Credit Facility [Line Items]	'
Letter of Credit and Reimbursement Agreement	$325
Letter of Credit, Interest Rate	2.00%
Letters of Credit Outstanding, Amount	$9.50
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%

Financial_Instruments_Narrativ

Financial Instruments - Narrative (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

31-May-14

Sep. 30, 2014

Dec. 31, 2013

31-May-14

Nov. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

Term Gas Supply Derivatives [Member]

Term Gas Supply Derivatives [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

2013 Liquefaction Credit Facilities [Member]

2013 Liquefaction Credit Facilities [Member]

Minimum [Member]

Maximum [Member]

Derivative gain (loss), net [Member]

Derivative gain (loss), net [Member]

Derivative gain (loss), net [Member]

Derivative gain (loss), net [Member]

Prepaid Expenses And Other Current Assets [Member]

Prepaid Expenses And Other Current Assets [Member]

Term Gas Supply Derivatives [Member]

Term Gas Supply Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Collateral, Right to Reclaim Cash

$0

$0

$300,000

$200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Term of Contract

'

'

'

'

'

'

'

'

'

'

'

'1 year

'7 years

'

'

'

'

Derivative Assets (Liabilities), at Fair Value, Net

-210,000

-156,000

-210,000

0

0

0

'

15,059,000

84,639,000

'

'

'

'

'

'

'

'

Derivative, Gain (Loss) on Derivative, Net

'

'

'

'

0

0

9,300,000

'

'

'

'

'

'

-129,000

-201,000

448,000

-976,000

Derivative, Notional Amount, in MMBtu

'

'

'

'

2,161,000,000

2,161,000,000

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Increase (Decrease)

'

'

'

'

'

'

'

'

'

($2,100,000,000)

($885,000,000)

'

'

'

'

'

'

Financial_Instruments_Fair_Val

Financial Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Sep. 30, 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]	'	'
Derivative Assets (Liabilities), at Fair Value, Net	($210)	($156)
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	-210	-156
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
Interest Rate Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Assets (Liabilities), at Fair Value, Net	15,059	84,639
Interest Rate Contract [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 Contract [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	15,059	84,639
Interest Rate Contract [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

Financial_Instruments_Fair_Val1

Financial Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Interest Rate Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivatives	$15,059	$84,639
LNG Inventory Derivatives [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivatives	-210	-156
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivatives	-210	0
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Noncurrent Derivative Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Assets, at Fair Value	32,161	98,123
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Derivative Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Liabilities, at Fair Value	($17,102)	($13,484)

Financial_Instruments_Derivati

Financial Instruments - Derivative Instruments, Gain (Loss) (Details) (USD $)	1 Months Ended	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended
	31-May-14	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
	Interest Rate Contract [Member]	Interest Rate Contract [Member]	Interest Rate Contract [Member]	Interest Rate Contract [Member]	Interest Rate Contract [Member]	LNG Inventory Derivatives [Member]	LNG Inventory Derivatives [Member]	LNG Inventory Derivatives [Member]	LNG Inventory Derivatives [Member]
		Derivative gain (loss), net [Member]	Derivative gain (loss), net [Member]	Derivative gain (loss), net [Member]	Derivative gain (loss), net [Member]	Gain (Loss) on Derivative Instruments [Member]	Gain (Loss) on Derivative Instruments [Member]	Gain (Loss) on Derivative Instruments [Member]	Gain (Loss) on Derivative Instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($9,300,000)	'	'	'	'	$129,000	$201,000	($448,000)	$976,000
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	'	$5,379,000	($22,481,000)	($89,222,000)	$60,707,000	'	'	'	'

Financial_Instruments_Schedule

Financial Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) (Interest Rate Contract [Member], Not Designated as Hedging Instrument [Member], USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Derivative [Line Items]	'
Derivative, Notional Amount	$20
Derivative, Effective Date	14-Aug-12
Derivative, Maturity Date	31-Jul-19
Derivative, Weighted Average Fixed Interest Rate Paid	1.98%
Interest Rate Derivative Assets, at Fair Value	'One-month LIBOR
Maximum [Member]	'
Derivative [Line Items]	'
Derivative, Notional Amount	$2,500

Financial_Instruments_Schedule1

Financial Instruments - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Details) (Interest Rate Contract [Member], USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	$0	($30)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	-167
Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0	21,297
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	$0	($5,806)

Financial_Instruments_Derivati1

Financial Instruments - Derivative Gross Presentation on Balance Sheets (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Gross Amounts Recognized	($210)	($156)
Derivative Liability, Gross Amounts Offset in our Balance Sheets	-210	-156
Net Amounts Presented in our Balance Sheets	0	0
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Net Amount	0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Gross Amounts Recognized	15,059	98,123
Derivative Asset, Gross Amounts Offset in our Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	15,059	98,123
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	'	0
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0	'
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset, Net Amount	15,059	98,123
Interest Rate Contract 2 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Gross Amounts Recognized	'	-13,484
Derivative Liability, Gross Amounts Offset in our Balance Sheets	'	0
Net Amounts Presented in our Balance Sheets	'	-13,484
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	'	0
Derivative, Collateral, Right to Reclaim Cash	'	0
Derivative Liability, Net Amount	'	($13,484)

Financial_Instruments_Schedule2

Financial Instruments - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	$6,517,787		$4,111,562
2021 Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	2,010,530		2,011,562
2021 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Payable, Fair Value Disclosure	2,045,714	[1]	1,961,273	[1]
2022 Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	1,000,000		1,000,000
2022 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Payable, Fair Value Disclosure	1,042,500	[1]	982,500	[1]
2023 Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	1,507,257		1,000,000
2023 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Payable, Fair Value Disclosure	1,507,257	[1]	935,000	[1]
2024 Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	2,000,000		0
2024 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Notes Payable, Fair Value Disclosure	2,010,000	[1]	0	[1]
2013 Sabine Pass Liquefaction Credit Facilities [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Carrying Amount, Long-term Debt	0		100,000
2013 Sabine Pass Liquefaction Credit Facilities [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Lines of Credit, Fair Value Disclosure	$0	[2]	$100,000	[2]
[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 September 30, 2014 and December 31, 2013, as applicable.
[2]	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

9 Months Ended

Share data in Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Feb. 01, 2013

Sep. 30, 2014

Feb. 01, 2013

Jan. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Service Agreements [Member]

Service Agreements [Member]

Service Agreements [Member]

Service Agreements [Member]

Subsidiary of Common Parent—Sabine Pass LNG [Member]

Cheniere Energy Investments, LLC [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Cheniere Energy, Inc. [Member]

Cheniere Marketing, LLC [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Operation and Maintenance Agreement [Member]

LNG Terminal Capacity Agreements [Member]

LNG Site Sublease Agreement [Member]

LNG Site Sublease Agreement [Member]

LNG Site Sublease Agreement [Member]

LNG Site Sublease Agreement [Member]

Management Services Agreement [Member]

LNG Sale and Purchase Agreement [Member]

item

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

bcf

item

LNG Terminal Capacity Agreements [Member]

LNG Terminal Capacity Agreements [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and administrative expense—affiliate

$17,215,000

$35,293,000

$52,644,000

$73,216,000

$17,100,000

$35,200,000

$52,300,000

$72,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Monthly fee as a percentage of capital expenditures incurred in the previous month

'

'

'

'

'

'

'

'

'

0.60%

'

'

'

'

'

2.40%

'

'

'

'

'

'

'

'

Related Party Transaction, Committed Monthly Fee

'

'

'

'

'

'

'

'

'

83,333

'

'

'

'

'

541,667

'

'

'

'

'

'

'

'

Loss Contingency, New Claims Filed, Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35

10

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

'

'

'

'

Period in Which Unawarded Shares Issuances May be Submitted for Stockholder Vote After Court Approval

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'90 days

'

'

Maximum Number of Shares That May Be Granted to Chief Executive Officer

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Memorandum Of Understanding Settlement Submission for Court Approval Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'60 days

'

'

Regasification capacity, in Bcf/d

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Committed Annual Fee

'

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Agreement Term

'

'

'

'

'

'

'

'

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Percentage Of Committed Monthly Payment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

0.00%

Portion of storage capacity reserved

'

'

'

'

'

'

'

'

'

'

41.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Terminal Use Agreement Maintenance Expense Including Affiliate

10,200,000

14,600,000

25,000,000

27,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incremental LNG Volume, Purchase Price Percentage of Henry Hub

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

115.00%

'

'

'

'

'

'

'

Incremental LNG Volume, Purchase Price Per MMBtu

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

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

400,000

400,000

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Transfers and Changes

'

'

'

'

'

'

'

'

$700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Supplemental Cash Flow Information [Abstract]	'	'
LNG terminal costs funded with accounts payable and accrued liabilities (including affiliates)	$270,761	$84,566