Cheniere Energy Partners (CQP) 10-Q 8 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Oct. 16, 2013
Entity [Abstract]	'	'
Entity Registrant Name	'Cheniere Energy Partners, L.P.	'
Entity Central Index Key	'0001383650	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	57,078,848
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$339,895	$419,292
Restricted cash and cash equivalents	210,076	92,519
Accounts and interest receivable	21,214	44
Advances to affiliate	25,737	4,987
LNG inventory	14,158	2,625
Prepaid expenses and other	7,884	7,084
Other - affiliate	4,255	6,572
Total current assets	623,219	533,123
Non-current restricted cash and cash equivalents	828,360	272,425
Property, plant and equipment, net	5,642,872	3,219,592
Debt issuance costs, net	340,856	220,949
Non-current derivative assets	64,309	0
Advances under long-term contracts	12,528	0
Other	58,574	19,698
Total assets	7,570,718	4,265,787
Current liabilities	'	'
Accounts payable	4,739	73,760
Accrued liabilities	141,788	47,848
Due to affiliates	52,474	7,562
Deferred revenue	26,585	26,540
Other	8,292	126
Total current liabilities	233,878	155,836
Long-term debt, net of discount	5,574,195	2,167,113
Deferred revenue	18,500	21,500
Deferred revenue - affiliate	17,173	14,720
Long term derivative liability	0	26,424
Other non-current liabilities	1,209	216
Commitments and contingencies	'	'
Partners' deficit	'	'
Creole Trail Pipeline Business equity	0	517,170
Common unitholders' interest (57.1 million units and 39.5 million units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	754,551	448,412
Class B unitholders' interest (145.3 million units and 133.3 million units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	-38,216	-37,342
Subordinated unitholders' interest (135.4 million units issued and outstanding at September 30, 2013 and December 31, 2012)	975,124	949,482
General partner's interest (2% interest with 6.9 million units and 6.3 million units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	34,304	29,496
Accumulated other comprehensive loss	0	-27,240
Total partners' equity	1,725,763	1,879,978
Total liabilities and partners' equity	$7,570,718	$4,265,787

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet Parentheticals	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
General partner ownership interest percentage	2.00%	2.00%
General partner, units Issued	6.9	6.3
General partner, units outstanding	6.9	6.3
Common Units	'	'
Partnership untiholders, units issued	57.1	39.5
Partnership untiholders, units outstanding	57.1	39.5
Class B Unit [Member]	'	'
Partnership untiholders, units issued	145.3	133.3
Partnership untiholders, units outstanding	145.3	133.3
Subordinated Units	'	'
Partnership untiholders, units issued	135.4	135.4
Partnership untiholders, units outstanding	135.4	135.4

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Revenues	'		'		'		'
Revenues	$66,646		$62,429	[1]	$199,052		$190,160	[1]
Revenuesbaffiliate	800		3,929	[1]	2,140		6,973	[1]
Total revenues	67,446		66,358	[1]	201,192		197,133	[1]
Expenses	'		'		'		'
Operating and maintenance expense	23,553		6,395	[1]	52,751		20,063	[1]
Operating and maintenance expense - affiliate	6,314		7,711	[1]	23,534		14,486	[1]
Depreciation expense	14,491		14,489	[1]	43,150		43,135	[1]
Development expense	1,355		4,229	[1]	8,157		35,369	[1]
Development expense - affiliate	133		102	[1]	1,195		2,365	[1]
General and administrative expense	2,718		4,737	[1]	8,521		9,235	[1]
General and administrative expense - affiliate	42,239		36,871	[1]	101,998		48,745	[1]
Total expenses	90,803		74,534	[1]	239,306		173,398	[1]
Income (loss) from operations	-23,357		-8,176	[1]	-38,114		23,735	[1]
Other income (expense)	'		'		'		'
Interest expense, net	-52,528		-43,626	[1]	-134,806		-130,554	[1]
Loss on early extinguishment of debt	0		0	[1]	-80,510		0	[1]
Derivative gain (loss), net	-22,335		287	[1]	55,706		-288	[1]
Other	111		145	[1]	873		289	[1]
Total other expense	-74,752		-43,194	[1]	-158,737		-130,553	[1]
Net loss	-98,109		-51,370	[1]	-196,851		-106,818	[1]
Net gain (loss) loss attributable to the Creole Trail Pipeline Business	244		-8,948	[1]	-18,150		-20,203	[1]
Net Income Loss Allocated to Partners	($98,353)		($42,422)	[1]	($178,701)		($86,615)	[1]
Weighted average number of common units outstanding used for basic and diluted net income per common unit calculation (shares)	57,079	[1]	'		53,277	[1]	'
[1]	Retrospectively adjusted as discussed in Note 2.

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Loss (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012
Statement of Other Comprehensive Income [Abstract]	'	'		'	'
Net loss	($98,109)	($51,370)	[1]	($196,851)	($106,818)	[1]
Loss on settlements retained in other comprehensive income	0	0	[1]	-30	0	[1]
Change in fair value of interest rate cash flow hedges	0	-29,676		21,297	-29,676
Losses reclassified into earnings as a result of disontinuatnce of cash flow hedge accounting	'	'		5,973	'
Total other comprehensive income	0	-29,676	[1]	27,240	-29,676	[1]
Comprehensive loss	($98,109)	($81,046)	[1]	($169,611)	($136,494)	[1]
[1]	Retrospectively adjusted as discussed in Note 2.

Consolidated_Statements_of_Par

Consolidated Statements of Partners' and Owners' Capital (Deficit) (USD $)	Total	Common Unitholders	Class B Unitholders	Subordinated Unitholders	General Partner Interest	Accumulated Other Comprehensive Loss [Member]	General Partner [Member]	Subordinated Units	Common Units
In Thousands, unless otherwise specified	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)
Total partners' equity at Dec. 31, 2012	$1,879,978	'	'	'	'	'	'	'	'
Accumulated Other Comprehensive Loss at Dec. 31, 2012	-27,240	'	'	'	'	-27,240	'	'	'
General Partners' Capital Account at Dec. 31, 2012	29,496	'	'	'	29,496	'	'	'	'
Common Unitholders Equity at Dec. 31, 2012	448,412	448,412	'	'	'	'	'	'	'
Subordinated Unitholders Equity at Dec. 31, 2012	949,482	'	'	949,482	'	'	'	'	'
Shares, Issued	'	57,078	145,333	'	'	'	6,894	135,384	'
Class B Unitholders Equity	'	'	-38,216	'	'	'	'	'	'
Partners' Capital Account, Units, Sale of Units	'	17,590	12,000	'	'	'	'	'	'
Predecessor Equity	0	'	'	'	'	'	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'	'	'
Net loss	-196,851	-48,741	0	-123,855	-6,105	0	'	'	'
Net gain (loss) loss attributable to the Creole Trail Pipeline Business	-18,150	'	'	'	'	'	'	'	'
Sale of common and general partner units	375,897	364,775	0	0	11,122	0	'	'	'
General Partners' Capital Account, Units Issued	'	'	'	'	'	'	604	'	'
Distributions	-66,633	-65,300	0	0	-1,333	0	'	'	'
Interest rate cash flow hedges	27,240	0	0	0	0	27,240	'	'	'
Contributions to Creole Trail Pipeline Business from Cheniere, net	20,896	'	'	'	'	'	'	'	'
Excess of acquired assets over purchase price	26,026	2,022	'	22,880	1,124	'	'	'	'
Issuance of Class B units associated with acquisition of Creole Trail Pipeline Business	179,126	'	179,126	'	0	0	'	'	'
Beneficial conversion feature of Class B units	0	53,383	-180,000	126,617	'	'	'	'	'
General Partners' Capital Account at Sep. 30, 2013	34,304	'	'	'	34,304	'	'	'	'
Accumulated Other Comprehensive Loss at Sep. 30, 2013	0	'	'	'	'	'	'	'	'
Common Unitholders Equity at Sep. 30, 2013	754,551	754,551	'	'	'	'	'	'	'
Subordinated Unitholders Equity at Sep. 30, 2013	$975,124	'	'	$975,124	'	'	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities	'	'
Net loss	($196,851,000)	($106,818,000)	[1]
Adjustments to reconcile net loss to net cash provided by operating activities:	'	'
Depreciation	43,150,000	43,135,000	[1]
Use of restricted cash and cash equivalents	147,982,000	36,676,000	[1]
Increase (Decrease) in Restricted Cash for Future Interest Payments	35,627,000	41,197,000
Non-cash LNG inventory write-downs	27,851,000	9,237,000	[1]
Amortization of debt discount	5,208,000	3,521,000	[1]
Amortization of debt issuance costs	3,383,000	8,373,000	[1]
Non-cash derivative (gain) loss, net	-55,049,000	300,000	[1]
Loss on early extinguishment of debt	-80,510,000	0	[1]
Other	705,000	3,736,000	[1]
Changes in operating assets and liabilities:	'	'
Accounts and interest receivable	-21,171,000	-24,619,000	[1]
Accounts receivablebaffiliate	-1,614,000	-855,000	[1]
Accounts payable and accrued liabilities	38,655,000	41,463,000	[1]
Due to affiliates	33,556,000	29,218,000	[1]
Deferred revenue	-2,955,000	-3,104,000	[1]
Advances to affiliate	-20,281,000	-3,627,000	[1]
LNG inventory	-33,248,000	-9,519,000	[1]
Other	-34,376,000	-4,003,000	[1]
Otherbaffiliate	4,081,000	3,143,140	[1]
Net cash used in operating activities	-16,091,000	-14,940,000	[1]
Cash flows from investing activities	'	'
LNG terminal costs, net	-2,449,360,000	-876,593,000	[1]
Use of restricted cash and cash equivalents	2,457,823,000	887,902,000	[1]
Purchase of Creole Trail Pipeline Business, net	-313,892,000	0	[1]
Advances under long-term contracts	-12,528,000	-15,009,000	[1]
Other	-5,120,000	-2,382,000	[1]
Net cash used in investing activities	-323,077,000	-6,082,000	[1]
Cash flows from financing activities	'	'
Proceeds from Sabine Pass Liquefaction Senior Notes, net	3,012,500,000	0	[1]
Proceeds from CTPL Credit Facility, net	391,978,000	0	[1]
Proceeds from 2013 Liquefaction Credit Facility	100,000,000	0	[1]
Proceeds from Sale of Interest in Partnership Unit	375,897,000	240,114,000	[1]
Proceeds from sale Of Class B Units	0	1,387,560,000	[1]
Contributions to Creole Trail Pipeline Business from Cheniere, net	20,896,000	9,608,000	[1]
Investment in restricted cash and cash equivalents	-3,243,670,000	-1,177,753,000	[1]
Debt issuance and deferred financing costs	-231,198,000	-210,126,000	[1]
Repayment of 2012 Liquefaction Credit Facility	100,000,000	100,000,000	[1]
Distributions to owners	-66,632,000	-40,696,000	[1]
Net cash provided by financing activities	259,771,000	308,707,000	[1]
Net increase (decrease) in cash and cash equivalents	-79,397,000	287,685,000	[1]
Cash and cash equivalentsbbeginning of period	419,292,000	81,415,000	[1]
Cash and cash equivalentsbend of period	$339,895,000	$369,100,000	[1]
[1]	Retrospectively adjusted as discussed in Note 2.

Organization_and_Nature_of_Ope

Organization and Nature of Operations Organization and Nature of Operations (Notes)	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and Nature of Operations	'
	ORGANIZATION AND NATURE OF OPERATIONS
	Cheniere Energy Partners, L.P. ("Cheniere Partners") is a publicly-traded Delaware limited partnership formed on November 21, 2006 by Cheniere Energy, Inc. ("Cheniere"). Unless the context requires otherwise, references to "Cheniere Partners", "we", "us" and "our" refer to Cheniere Partners and its subsidiaries.
	We were formed to own and operate the Sabine Pass liquefied natural gas ("LNG") terminal located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast. The Sabine Pass LNG terminal has regasification facilities owned by our wholly owned subsidiary, Sabine Pass LNG, L.P. ("Sabine Pass LNG"), that includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d. Approximately one-half of the receiving capacity at the Sabine Pass LNG terminal is contracted to two multinational energy companies.
	We are developing natural gas liquefaction facilities (the "Liquefaction Project") at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, Sabine Pass Liquefaction, LLC ("Sabine Pass Liquefaction"). We plan to construct up to six Trains, which are in various stages of development. Each Train is expected to have nominal production capacity of approximately 4.5 million tonnes per annum ("mtpa") of LNG.
	In May 2013, we acquired Cheniere's ownership interests in Cheniere Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, the "Creole Trail Pipeline Business"), thereby providing us with ownership of a 94-mile pipeline interconnecting the Sabine Pass LNG terminal with a number of large interstate pipelines (the "Creole Trail Pipeline"). We acquired the Creole Trail Pipeline Business for $480.0 million and reimbursed Cheniere $13.9 million for certain expenditures incurred prior to the closing date.  Concurrent with the Creole Trail Pipeline Business acquisition closing, we issued 12.0 million Class B units to Cheniere at a price of $15.00 per Class B unit for aggregate consideration of $180.0 million pursuant to a unit purchase agreement with Cheniere Class B Units Holdings, LLC, a wholly owned subsidiary of Cheniere.  As a result of the two transactions, we paid Cheniere net cash of $313.9 million. See Note 2—"Basis of Presentation".

Basis_of_Presentation_Notes

Basis of Presentation (Notes)	9 Months Ended
	Sep. 30, 2013
Basis of Presentation [Abstract]	'
Basis of Presentation	'
	BASIS OF PRESENTATION
	The accompanying unaudited Consolidated Financial Statements of Cheniere Energy Partners, L.P. have been prepared in accordance with generally accepted accounting principles in the United States ("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.
	These consolidated financial statements include our accounts and the assets, liabilities and operations of the Creole Trail Pipeline Business. The effect of including the prior results of the Creole Trail Pipeline Business is reported as net loss attributable to Creole Trail Pipeline Business in our Consolidated Statement of Operations and Creole Trail Pipeline Business equity in our Consolidated Balance Sheets and Consolidated Statements of Partners' and Owners' Equity. This purchase has been accounted for as a transfer of net assets between entities under common control.
	We recognize transfers of net assets between entities under common control at Cheniere's historical basis in the net assets sold. In addition, transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. The difference between the purchase price and Cheniere's basis in the net assets sold, if any, is recognized as an adjustment to partners' equity.
	Subsequent to the Creole Trail Pipeline Business acquisition, we control CTPL's operating and financial decisions and policies and have consolidated CTPL in our financial statements. Our consolidated financial statements and all other financial information included in this report have been retrospectively adjusted to assume that our acquisition of the Creole Trail Pipeline Business from Cheniere had occurred at the date when the Creole Trail Pipeline Business met the accounting requirements for entities under common control (the date of our inception since both we and the Creole Trail Pipeline Business were formed by Cheniere). Net income (loss) attributable to the Creole Trail Pipeline Business for periods prior to the acquisition is not allocated to the common units for purposes of calculating net income (loss) per common unit.
	Results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2013.
	We are not subject to either federal or state income tax, as our partners are taxed individually on their allocable share of our taxable income.
	Certain reclassifications have been made to prior period information to conform to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows. For further information, refer to the consolidated financial statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2012, as amended by Amendment No. 1 on Form 10-K/A.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents	9 Months Ended
	Sep. 30, 2013
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 Consolidated Balance Sheets.
	Certain amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal for a certain amount of time. Prior to being restricted and after the restriction is lifted such amounts flow though cash and cash equivalents. For these amounts, we have presented increases and decreases as "Investments in (releases of) restricted cash and cash equivalents" in our Consolidated Statement of Cash Flows.
	Certain other amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal and will not become available to us as cash and cash equivalents. For these amounts, we have presented increases and decreases as "Investments in (uses of) of restricted cash and cash equivalents" in our Consolidated Statement of Cash Flows. These amounts that represent non-cash transactions within our Consolidated Statement of Cash Flows present the effect of sources and uses of restricted cash and cash equivalents as they relate to the changes to assets and liabilities in our Consolidated Balance Sheets. This presentation does not impact the total amount of operating, investing or financing cash flows related to these items, however , they are presented on a gross basis within each of those categories so as to reconcile the change in non-cash activity that occurs on the balance sheet from period to period.
	Restricted cash and cash equivalents include the following:
	Sabine Pass LNG Senior Notes Debt Service Reserve
	Sabine Pass LNG has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of Senior Secured Notes due 2016 (the "2016 Notes") and $420.0 million of Senior Secured Notes due 2020 (the "2020 Notes"). See Note 7—"Long-Term Debt". Collectively, the 2016 Notes and the 2020 Notes are referred to as the "Sabine Pass LNG Senior Notes." Under the indentures governing the Sabine Pass LNG Senior Notes (the "Sabine Pass LNG Indentures"), except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied, including that there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass LNG Indentures.
	As of September 30, 2013 and December 31, 2012, we classified $53.0 million and $17.4 million, respectively, as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of September 30, 2013 and December 31, 2012, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash and cash equivalents. These cash accounts are controlled by a collateral trustee, and, therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets.
	Liquefaction Reserve
	In July 2012, Sabine Pass Liquefaction closed on a $3.6 billion senior secured credit facility (the "2012 Liquefaction Credit Facility"). In February and April 2013, Sabine Pass Liquefaction entered into $2.0 billion, before premium, of Senior Secured Notes due in 2021 (the "2021 Sabine Pass Liquefaction Senior Notes") and $1.0 billion of Senior Secured Notes due in 2023 (the "2023 Sabine Pass Liquefaction Senior Notes" and collectively with the 2021 Sabine Pass Liquefaction Senior Notes, the "Sabine Pass Liquefaction Senior Notes"). In May 2013, Sabine Pass Liquefaction closed four credit facilities aggregating $5.9 billion (collectively the "2013 Liquefaction Credit Facilities"), which amended and restated the 2012 Liquefaction Credit Facility. See Note 7—"Long-Term Debt". Under the terms and conditions of the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to deposit all cash received into collateral accounts controlled by a collateral trustee. Therefore, all of Sabine Pass Liquefaction's cash and cash equivalents are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets. As of September 30, 2013 and December 31, 2012, we classified $133.5 million and $75.1 million, respectively, as current restricted cash and cash equivalents held by Sabine Pass Liquefaction for the payment of current liabilities related to the Liquefaction Project, and $665.1 million and $196.3 million, respectively, as non-current restricted cash and cash equivalents held by Sabine Pass Liquefaction for future Liquefaction Project construction costs.
	CTPL Reserve
	In May 2013, CTPL entered into a $400.0 million term loan facility (the "CTPL Credit Facility"). As of September 30, 2013, we classified $23.5 million and $87.2 million as current and non-current restricted cash and cash equivalents, respectively, held by CTPL because such funds may only be used for modifications of the Creole Trail Pipeline in order to enable bi-directional natural gas flow and for the payment of interest during construction of such modifications.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	9 Months Ended
	Sep. 30, 2013
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,
		2013			2012
	LNG terminal costs
	LNG terminal	$	2,224,364		$	2,224,230
	LNG terminal construction-in-process	3,694,355			1,228,647
	LNG site and related costs, net	150			156
	Accumulated depreciation	(276,960		)	(234,349		)
	Total LNG terminal costs, net	5,641,909			3,218,684
	Fixed assets
	Computer and office equipment	474			368
	Vehicles	884			704
	Machinery and equipment	1,490			1,473
	Other	837			760
	Accumulated depreciation	(2,722		)	(2,397		)
	Total fixed assets, net	963			908
	Property, plant and equipment, net	$	5,642,872		$	3,219,592
	Depreciation expense related to the Sabine Pass LNG terminal totaled $14.4 million for each of the three months ended September 30, 2013 and 2012. Depreciation expense related to the Sabine Pass LNG terminal totaled $42.8 million for the nine months ended September 30, 2013 and 2012.
	In June 2012, we began capitalizing costs associated with Train 1 and Train 2 of the Liquefaction Project, and in May 2013, we began capitalizing costs associated with Train 3 and Train 4 of the Liquefaction Project. For the three months ended September 30, 2013 and 2012, we capitalized $30.2 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively. For the nine months ended September 30, 2013 and 2012, we capitalized $125.0 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively.

Financial_Instruments

Financial Instruments	9 Months Ended
	Sep. 30, 2013
Financial Instruments [Abstract]	'
Financial Instruments	'
	FINANCIAL INSTRUMENTS
	Derivative Instruments
	We have entered into certain instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory ("LNG Inventory Derivatives") and to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal ("Fuel Derivatives"), 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, 2013 and December 31, 2012, which are classified as other current assets, other current liabilities, other non-current assets and other non-current liabilities in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		30-Sep-13																31-Dec-12
		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	$	—			$	219			$	—			$	219			$	—			$	232			$	—	$	232
	Fuel Derivatives (liability)	—				(227		)		—				(227		)		—				(98		)		—		(98		)
	Interest Rate Derivatives asset (liability)	—				56,039				—				56,039				—				(26,424		)		—		(26,424		)
	The estimated fair values of our LNG Inventory Derivatives and Fuel Derivatives are the amount 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. Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for net settlement.
	Commodity Derivatives
	We recognize all derivative instruments that qualify for derivative accounting treatment as either assets or liabilities and measure those instruments at fair value unless they qualify for, and we elect, the normal purchase normal sale exemption.  For transactions in which we have elected the normal purchase normal sale exemption, gains and losses are not reflected on our Consolidated Statements of Operations until the period of delivery. For those instruments accounted for as derivatives, including our LNG Inventory Derivatives and certain of our Fuel Derivatives, changes in fair value 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 Fuel Derivatives or our LNG Inventory Derivatives are in an asset position. Except for the fuel hedges with our affiliate described below, our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our commodity derivative activities.  Collateral of $0.9 million deposited for such contracts, which has not been reflected in the derivative fair value tables, is included in the other current assets balance as of September 30, 2013 and December 31, 2012.
	During the second quarter of 2013, Sabine Pass LNG began to enter into forward contracts under its master service agreement with Cheniere Marketing, LLC ("Cheniere Marketing"), a wholly owned subsidiary of Cheniere, to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal. Sabine Pass LNG elected to account for these physical hedges of future fuel purchases as normal purchase normal sale transactions, exempt from fair value accounting. Sabine Pass LNG had not posted collateral with Cheniere Marketing for such forward contracts as of September 30, 2013.
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			September 30, 2013				December 31, 2012
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	219			$	232
	Fuel Derivatives liability	Prepaid expenses and other			(227		)		(98		)
	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives recorded in revenues on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	LNG Inventory Derivatives gain (loss)	$	—			$	(228	)		$	(442	)		$	697
	The following table (in thousands) shows the changes in the fair value and settlements of our Fuel Derivatives and LNG Inventory Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	LNG Inventory Derivatives gain	$	201			$	—			$	976			$	—
	Fuel Derivatives gain (loss) (1)	(55		)		287				(3		)		(288		)
	(1)Excludes settlements of hedges of the exposure to price risk attributable to future purchases of natural gas to be utilized
	as fuel to operate the Sabine Pass LNG terminal for which Sabine Pass LNG has elected the normal purchase normal sale exemption from derivative accounting.
	Interest Rate Derivatives
	In August 2012 and June 2013, Sabine Pass Liquefaction 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.
	Sabine Pass Liquefaction 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 Consolidated 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 Consolidated 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 Consolidated 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.
	Sabine Pass Liquefaction 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 the Consolidated 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 Sabine Pass Liquefaction Senior Notes described in Note 8—"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 the Consolidated Balance Sheets, and changes in fair value subsequent to their de-designation date are recorded as derivative gain (loss) within the Consolidated 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 Sabine Pass Liquefaction 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 drawn portions of 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 Consolidated Statements of Operations.
	At September 30, 2013, Sabine Pass Liquefaction 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	million		$	2.9	billion		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
	Interest Rate Derivatives - Not Designated		—				$	671	million		5-Jun-13		28-May-20		2.05%		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, 2013				December 31, 2012
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	64,309			$	—
	Interest Rate Derivatives - Designated		Non-current derivative liabilities		—				21,290
	Interest Rate Derivatives - Not Designated		Other current liabilities		8,270				—
	Interest Rate Derivatives - Not Designated		Non-current derivative liabilities		—				5,134
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the three months ended September 30, 2013 and 2012:
		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
		2013				2012				2013				2012				2013				2012
	Interest Rate Derivatives - Designated	$	—			$	(29,676	)		$	—			$	—			$	—			$	—
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the nine months ended September 30, 2013 and 2012:
		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
		2013				2012				2013				2012				2013				2012
	Interest Rate Derivatives - Designated	$	21,297			$	(29,676	)		$	—			$	—			$	(5,806	)		$	—
	Interest Rate Derivatives - Settlements	(30		)		—				—				—				(167		)		—
	The following table (in thousands) shows the changes in the fair value of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	Interest Rate Derivatives - Not Designated gain (loss)	$	(22,481	)		$	—			$	60,707			$	—
	Balance Sheet Presentation
Our commodity and interest rate derivatives are presented on a net basis on our Consolidated Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
		Gross Amounts Recognized					Gross Amounts Offset in the Consolidated Balance Sheet				Net Amounts Presented in the Consolidated Balance Sheet				Gross Amounts Not Offset in the Consolidated Balance Sheet
Offsetting Derivative Assets (Liabilities)															Derivative Instrument				Cash Collateral Received (Paid)				Net Amount
As of September 30, 2013:
Fuel Derivatives		$	(227	)			$	(227	)		$	—			$	—			$	—			$	—
LNG Inventory Derivatives		219					—				219				—				—				219
Interest Rate Derivatives - Not Designated		64,309					—				64,309				—				—				64,309
Interest Rate Derivatives - Not Designated		(8,270		)			—				(8,270		)		—				—				(8,270		)
As of December 31, 2012:					—
Fuel Derivatives		(98		)			(98		)		—				—				—				—
LNG Inventory Derivatives		232					—				232				—				—				232
Interest Rate Derivatives - Designated		(21,290		)			—				(21,290		)		—				—				(21,290		)
Interest Rate Derivatives - Not Designated		(5,134		)			—				(5,134		)		—				—				(5,134		)
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 Consolidated 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.
Other Financial Instruments (in thousands):
		September 30, 2013								December 31, 2012
		Carrying				Estimated				Carrying				Estimated
		Amount				Fair Value				Amount				Fair Value
2016 Notes, net of discount (1)		$	1,650,634			$	1,811,570			$	1,647,113			$	1,824,177
2020 Notes (1)		420,000				425,250				420,000				437,850
2021 Sabine Pass Liquefaction Senior Notes (1)		2,011,897				1,951,540				—				—
2023 Sabine Pass Liquefaction Senior Notes (1)		1,000,000				952,500				—				—
2012 Liquefaction Credit Facility (2)		—				—				100,000				100,000
2013 Liquefaction Credit Facilities (2)		100,000				100,000				—				—
CTPL Credit Facility (3)		391,665				400,000				—				—
-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, 2013 and December 31, 2012, 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 Sabine Pass Liquefaction has the ability to call this debt at anytime without penalty.
-3	The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and CTPL has the ability to call this debt at anytime without penalty.

Accrued_Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2013
Accrued Liabilities [Abstract]	'
Accrued Liabilities	'
	ACCRUED LIABILITIES
	As of September 30, 2013 and December 31, 2012, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		September 30,		December 31,
		2013		2012
	Interest and related debt fees	$	97,758	$	16,327
	Affiliate	51,419		5,744
	LNG liquefaction costs	33,589		26,131
	LNG terminal costs	1,650		977
	Other	8,791		4,413
	Total accrued liabilities (including affiliate)	$	193,207	$	53,592

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Long-term Debt, Unclassified [Abstract]	'
Long-term Debt	'
	LONG-TERM DEBT
	As of September 30, 2013 and December 31, 2012, our long-term debt consisted of the following (in thousands):
		September 30,			December 31,
		2013			2012
	Long-term debt
	2016 Notes	$	1,665,500		$	1,665,500
	2020 Notes	420,000			420,000
	2021 Sabine Pass Liquefaction Senior Notes	2,000,000			—
	2023 Sabine Pass Liquefaction Senior Notes	1,000,000			—
	2012 Liquefaction Credit Facility	—			100,000
	2013 Liquefaction Credit Facilities	100,000			—
	CTPL Credit Facility	400,000			—
	Total long-term debt	5,585,500			2,185,500
	Long-term debt premium (discount)
	2016 Notes	(14,866		)	(18,387		)
	2021 Sabine Pass Liquefaction Senior Notes	11,897			—
	CTPL Credit Facility	(8,336		)	—
	Total long-term debt, net	$	5,574,195		$	2,167,113
	Sabine Pass LNG Senior Notes
	As of September 30, 2013 and December 31, 2012, Sabine Pass LNG had an aggregate principal amount of $1,665.5 million, before discount, of the 2016 Notes and $420.0 million of the 2020 Notes outstanding. Borrowings under the 2016 Notes and 2020 Notes bear interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Notes and the 2020 Notes are substantially similar. Interest on the 2016 Notes is payable semi-annually in arrears on May 30 and November 30 of each year. Interest on the 2020 Notes is payable semi-annually in arrears on May 1 and November 1 of each year. Subject to permitted liens, the Sabine Pass LNG Senior Notes are secured on a first-priority basis by a security interest in all of Sabine Pass LNG's equity interests and substantially all of its operating assets.
	Sabine Pass LNG may redeem some or all of its 2016 Notes at any time, and from time to time, at the redemption prices specified in the indenture governing the 2016 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may redeem all or part of its 2020 Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may also, at its option, redeem all or part of the 2020 Notes at any time prior to November 1, 2016, at a "make-whole" price set forth in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, Sabine Pass LNG may redeem up to 35% of the aggregate principal amount of the 2020 Notes at a redemption price of 106.5% of the principal amount of the 2020 Notes to be redeemed, plus accrued and unpaid interest, if any, to the redemption date, in an amount not to exceed the net proceeds of one or more completed equity offerings as long as Sabine Pass LNG redeems the 2020 Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Notes originally issued remains outstanding after the redemption.
	Under the Sabine Pass LNG Indentures, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass LNG Indentures. During the three months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $93.0 million and $36.2 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures. During the nine months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $242.1 million and $182.9 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures.
	Sabine Pass Liquefaction Senior Notes
	In February 2013 and April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Sabine Pass Liquefaction Senior Notes. In April 2013, Sabine Pass Liquefaction also issued $1.0 billion of the 2023 Sabine Pass Liquefaction Senior Notes. Borrowings under the Sabine Pass Liquefaction Senior Notes bear interest at a fixed rate of 5.625%. Interest on the 2021 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on February 1 and August 1 of each year. Interest on the 2023 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on April 15 and October 15 of each year.
	The terms of the 2021 Sabine Pass Liquefaction Senior Notes and the 2023 Sabine Pass Liquefaction 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 Sabine Pass Liquefaction's ability and the ability of Sabine Pass Liquefaction's 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 Sabine Pass Liquefaction's 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 Sabine Pass Liquefaction's assets and enter into certain LNG sales contracts. Subject to permitted liens, the Sabine Pass Liquefaction Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in Sabine Pass Liquefaction and substantially all of Sabine Pass Liquefaction's assets. Sabine Pass Liquefaction may not make any distributions until, among other requirements, substantial completion of Train 1 and Train 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 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction may redeem all or a part of the Sabine Pass Liquefaction 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. Sabine Pass Liquefaction also may at any time on or after November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, redeem the Sabine Pass Liquefaction Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the Sabine Pass Liquefaction Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.
	In connection with the issuances of the Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction also entered into registration rights agreements (the "Liquefaction Registration Rights Agreements"). Under the Liquefaction Registration Rights Agreements, Sabine Pass Liquefaction has agreed to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to an offer to exchange the Sabine Pass Liquefaction Senior Notes for a like aggregate principal amount of SEC-registered notes with terms identical in all material respects to the 2021 Sabine Pass Liquefaction Senior Notes and 2023 Sabine Pass Liquefaction Senior Notes (other than with respect to restrictions on transfer or to any increase in annual interest rate) within 360 days after February 1, 2013 for $1.5 billion of the 2021 Sabine Pass Liquefaction Senior Notes and within 295 days after April 16, 2013 for $500.0 million of the 2021 Sabine Pass Liquefaction Senior Notes and all of the 2023 Sabine Pass Liquefaction Senior Notes. Under specified circumstances, Sabine Pass Liquefaction may be required to file a shelf registration statement to cover resales of the Sabine Pass Liquefaction Senior Notes. If Sabine Pass Liquefaction fails to satisfy these obligations, Sabine Pass Liquefaction may be required to pay additional interest to holders of the Sabine Pass Liquefaction Senior Notes under certain circumstances.
	2013 Liquefaction Credit Facilities
	In May 2013, Sabine Pass Liquefaction closed 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 LNG 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 LNG 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. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent.
	Borrowings under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at Sabine Pass Liquefaction's election, the London Interbank Offered Rate ("LIBOR") or the base rate, plus the applicable margin. The applicable margins for LIBOR loans prior to, and after, the completion of Train 4 range from 2.3% to 3.0% and 2.3% to 3.25%, respectively, 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 Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144.0 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. Annual administrative fees must also be paid to the agent and the trustee. The principal of loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing upon the earlier of the last day of the first calendar quarter ending at least three months following the completion of Train 4 of the Liquefaction Project and 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 Sabine Pass Liquefaction 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 Consolidated Balance Sheets.
	The 2013 Liquefaction Credit Facilities contain conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2013 Liquefaction Credit Facilities are secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.
	Under the terms of the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to hedge not less than 75% of the variable interest rate exposure of its projected outstanding borrowings, calculated on a weighted average basis in comparison to its anticipated draw of principal. See Note 5— "Financial Instruments".
	2012 Liquefaction Credit Facility
	In July 2012, Sabine Pass Liquefaction entered into the $3.6 billion 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 Train 1 and Train 2 of the Liquefaction Project. 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.
	The 2012 Liquefaction Credit Facility had a maturity date of the earlier of July 31, 2019 or the second anniversary of the completion date of Train 1 and Train 2 of the Liquefaction Project, as defined in the 2012 Liquefaction Credit Facility. Borrowings under the 2012 Liquefaction Credit Facility could have been refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2012 Liquefaction Credit Facility in August 2012 after meeting the required conditions precedent.
	Borrowings under the 2012 Liquefaction Credit Facility bore interest at a variable rate equal to, at Sabine Pass Liquefaction's election, LIBOR or the base rate, plus the applicable margin. The applicable margin for LIBOR loans was 3.50% during construction and 3.75% during operations. Interest on LIBOR loans was due and payable at the end of each LIBOR period. The 2012 Liquefaction Credit Facility required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $178 million and provided 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. Annual administrative fees were also required to be paid to the agent and the trustee. The principal of loans made under the 2012 Liquefaction Credit Facility had to be repaid in quarterly installments, commencing with the last day of the first calendar quarter ending at least three months following the completion of Train 1 and Train 2 of the Liquefaction Project. Scheduled repayments were based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2012 Liquefaction Credit Facility.
	Under the terms and conditions of the 2012 Liquefaction Credit Facility, all cash held by Sabine Pass Liquefaction was controlled by the collateral agent. These funds could only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and the cash balance of $100.0 million held in these accounts as of December 31, 2012 was classified as restricted on our Consolidated Balance Sheets.
	The 2012 Liquefaction Credit Facility contained conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2012 Liquefaction Credit Facility were secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction, and a security interest in Cheniere Partners' rights under its Unit Purchase Agreement with Blackstone CQP Holdco LP ("Blackstone"), dated May 14, 2012, on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.
	Under the terms of the 2012 Liquefaction Credit Facility, Sabine Pass Liquefaction was required to hedge not less than 75% of the variable interest rate exposure of its projected outstanding borrowings, calculated on a weighted average basis in comparison to its anticipated draw of principal. See Note 5— "Financial Instruments".
	In February 2013, Sabine Pass Liquefaction issued the 2021 Sabine Pass Liquefaction Senior Notes to refinance a portion of the 2012 Liquefaction Credit Facility, and a portion of available commitments pursuant to the 2012 Liquefaction Credit Facility was suspended. In April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $500.0 million of additional 2021 Sabine Pass Liquefaction Senior Notes and $1.0 billion of 2023 Sabine Pass Liquefaction Senior Notes, and as a result, 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.
	CTPL Credit Facility
	In May 2013, CTPL entered into the CTPL Credit Facility, which will be used to fund modifications to the Creole Trail Pipeline and for general business purposes. CTPL incurred $10.0 million of direct lender fees that were recorded as a debt discount. The CTPL Credit Facility matures in 2017 when the full amount of the outstanding principal obligations must be repaid. CTPL's loans may be repaid, in whole or in part, at any time without premium or penalty. As of September 30, 2013, CTPL had borrowed the full amount of $400.0 million available under the CTPL Credit Facility.
	Borrowings under the CTPL Credit Facility bear interest at a variable rate per annum equal to, at CTPL's election, LIBOR or the base rate, plus the applicable margin. The applicable margin for LIBOR loans is 3.25%. Interest on LIBOR loans is due and payable at the end of each LIBOR period.
	Under the terms and conditions of the CTPL Credit Facility, all cash reserved to pay interest during construction is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions, and are classified as restricted on our Consolidated Balance Sheets. CTPL is also required to pay annual fees to the administrative and collateral agents.
	The CTPL Credit Facility contains customary affirmative and negative covenants. The obligations of CTPL under the CTPL Credit Facility are secured by a first priority lien on substantially all of the personal property of CTPL and all of the general partner and limited partner interests in CTPL.
	Cheniere Partners has guaranteed (i) the obligations of CTPL under the CTPL Credit Facility if the maturity of the CTPL loans is accelerated following the termination by Sabine Pass Liquefaction of a transportation precedent agreement in limited circumstances and (ii) the obligations of Cheniere Energy Investments, LLC ("Cheniere Investments"), Cheniere Partners' wholly owned subsidiary, in connection with its obligations under an equity contribution agreement (a) to pay operating expenses of CTPL until CTPL receives revenues under a service agreement with Sabine Pass Liquefaction and (b) to fund interest payments on the CTPL loans after the funds in an interest reserve account have been exhausted.

Description_of_Equity_Interest

Description of Equity Interests	9 Months Ended
	Sep. 30, 2013
Description of Equity Interests [Abstract]	'
Description of Equity Interests	'
	DESCRIPTION OF EQUITY INTERESTS
	The common units, Class B units and subordinated units represent limited partner interests in us. The holders of the units are entitled to participate in partnership distributions and exercise the rights and privileges available to limited partners under our partnership agreement.
	The general partner interest is entitled to at least 2% of all distributions made by us. In addition, the general partner holds incentive distribution rights, which allow the general partner to receive a higher percentage of quarterly distributions of available cash from operating surplus after the initial quarterly distributions have been achieved and as additional target levels are met. The higher percentages range from 15% up to 50%.
	The common units have the right to receive initial quarterly distributions of $0.425, plus any arrearages thereon, before any distribution is made to the holders of the subordinated units. Subordinated units will convert into common units on a one-for-one basis when we meet financial tests specified in the partnership agreement. Although common and subordinated unitholders are not obligated to fund losses of the partnership, their capital accounts, which would be considered in allocating the net assets of the partnership were it to be liquidated, continue to share in losses.
	During 2012, Blackstone and Cheniere completed their purchases of newly created Cheniere Partners Class B units ("Class B units") for total consideration of $1.5 billion and $500.0 million, respectively. Proceeds from the financings are being used to fund a portion of the costs of developing, constructing and placing into service the Liquefaction Project. In May 2013, Cheniere purchased an additional 12.0 million Class B units for consideration of $180.0 million in connection with Cheniere Partners' acquisition of the Creole Trail Pipeline Business described in Note 1—"Organization and Nature of Operations".  The Class B units are subject to conversion, mandatorily or at the option of the holders of the Class B units under specified circumstances, into a number of common units based on the then-applicable conversion value of the Class B units. On a quarterly basis beginning on the initial purchase of the Class B units, and ending on the conversion date of the Class B units, the conversion value of the Class B units increases at a compounded rate of 3.5% per quarter, subject to an additional upward adjustment for certain equity and debt financings. The Class B units are not entitled to cash distributions except in the event of our liquidation, our merger, consolidation or other combination with another person or the sale of all or substantially all of our assets. The holders of Class B units have a preference over the holders of the subordinated units in the event of our liquidation, our merger, consolidation or other combination with another person or the sale of all or substantially all of our assets. The Class B units will mandatorily convert into common units on the first business day following the record date with respect to Cheniere Partners' first distribution (the "Mandatory Conversion Date") after the earlier of the substantial completion date of Train 3 or August 9, 2017, although if a notice to proceed is given to Bechtel for Train 3 prior to August 9, 2017, the Mandatory Conversion Date will be the substantial completion date of Train 3. The notice to proceed was given to Bechtel on May 28, 2013. We currently expect the substantial completion date of Train 3 to occur before March 31, 2017. If the Class B units are not mandatorily converted by July 2019, the holders of the Class B units have the option to convert the Class B units into common units at that time.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	As of September 30, 2013 and December 31, 2012, we had $25.7 million and $5.0 million of advances to affiliates, respectively. In addition, we have entered into the following related party transactions:
	LNG Terminal Capacity Agreements
	Terminal Use Agreement
	Sabine Pass Liquefaction obtained approximately 2.0 Bcf/d of regasification capacity under a terminal use agreement ("TUA") with Sabine Pass LNG as a result of an assignment in July 2012 by Cheniere Energy Investments, LLC ("Cheniere Investments"), our wholly owned subsidiary, of its rights, title and interest under its TUA with Sabine Pass LNG. Sabine Pass Liquefaction is obligated to make monthly capacity payments to Sabine Pass LNG aggregating approximately $250 million per year, continuing until at least 20 years after Sabine Pass Liquefaction delivers its first commercial cargo at the Liquefaction Project, which may occur as early as late 2015.
	In connection with Sabine Pass Liquefaction's TUA, Sabine Pass Liquefaction is required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. During the three and nine months ended September 30, 2013, we recorded $14.4 million and $27.3 million, respectively, as operating and maintenance expense related to this obligation.
	Cheniere Investments, Sabine Pass Liquefaction and Sabine Pass LNG entered into a terminal use rights assignment and agreement ("TURA") pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction's reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to Sabine Pass LNG. However, the revenue earned by Sabine Pass LNG from the capacity payments made under the TUA and the loss incurred by Cheniere Investments under the TURA are eliminated upon consolidation of our financial statements. We have guaranteed the obligations of Sabine Pass Liquefaction under its TUA and the obligations of Cheniere Investments under the TURA.
	In an effort to utilize Cheniere Investments’ reserved capacity under its TURA during construction of the Liquefaction Project, Cheniere Marketing has entered into an amended and restated variable capacity rights agreement with Cheniere Investments ("amended and restated VCRA") pursuant to which Cheniere Marketing is obligated to pay Cheniere Investments 80% of the expected gross margin of each cargo of LNG that Cheniere Marketing arranges for delivery to the Sabine Pass LNG terminal. During the term of the amended and restated VCRA, Cheniere Marketing is responsible for the payment of taxes and new regulatory costs paid by Cheniere Investments under the TURA. We recorded zero and $3.2 million revenues—affiliate from Cheniere Marketing in the three months ended September 30, 2013 and 2012, respectively, related to the amended and restated VCRA. We recorded zero and $4.9 million of revenues—affiliate from Cheniere Marketing in the nine months ended September 30, 2013 and 2012, respectively, related to the amended and restated VCRA.
	LNG Sale and Purchase Agreement ("SPA")
	Cheniere Marketing has entered into an SPA with Sabine Pass Liquefaction to purchase, at Cheniere Marketing's option, up to 104,000,000 MMBtu of LNG per annum produced from Train 1 through Train 4. Sabine Pass Liquefaction has the right each year during the term to reduce the annual contract quantity based on its assessment of how much LNG it can produce in excess of that required for other customers. Cheniere Marketing may purchase incremental LNG volumes at a price of 115% of Henry Hub plus: up to $3.00 per MMBtu for the most profitable 36,000,000 MMBtu of cargoes sold each year by Cheniere Marketing; and then 20% of net profits of the remaining 68,000,000 MMBtu sold each year by Cheniere Marketing.
	LNG Lease Agreement
	In September 2011, Cheniere Investments entered into an agreement in the form of a lease (the "LNG Lease Agreement") with Cheniere Marketing that enables Cheniere Investments to supply the Sabine Pass LNG terminal with LNG to maintain proper LNG inventory levels and temperature. The LNG Lease Agreement also enables Cheniere Investments to hedge the exposure to variability in expected future cash flows of the LNG inventory. Under the terms of the LNG Lease Agreement, Cheniere Marketing funds all activities related to the purchase and hedging of the LNG, and Cheniere Investments reimburses Cheniere Marketing for all costs and assumes full price risk associated with these activities.
	As a result of Cheniere Investments assuming full price risk associated with the LNG Lease Agreement, LNG inventory purchased by Cheniere Marketing under this arrangement is classified as LNG inventory—affiliate on our Consolidated Balance Sheets, and is recorded at cost and subject to lower-of-cost-or-market ("LCM") adjustments at the end of each period. LNG inventory—affiliate cost is determined using the average cost method. Recoveries of losses resulting from interim period LCM adjustments are made due to market price recoveries on the same LNG inventory—affiliate in the same fiscal year and are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. Gains or losses on the sale of LNG inventory—affiliate and LCM adjustments are recorded as revenues on our Consolidated Statements of Operations. As of September 30, 2013, we had 75,000 MMBtu of LNG inventory—affiliate recorded at $0.2 million on our Consolidated Balance Sheets, and as of December 31, 2012, we had 1,369,000 MMBtu of LNG inventory—affiliate recorded at $4.4 million on our Consolidated Balance Sheets. During the three months ended September 30, 2013 and 2012, we recognized a gain of zero and $0.1 million, respectively, as a result of LCM adjustments to our LNG inventory—affiliate. During the nine months ended September 30, 2013 and 2012, we recognized a loss of zero and $0.5 million, respectively, as a result of LCM adjustments to our LNG inventory—affiliate.
	Cheniere Marketing has entered into financial derivatives, on our behalf, to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory under the LNG Lease Agreement. The fair value of these derivative instruments at September 30, 2013 and December 31, 2012 was a derivative asset of zero and $0.2 million, respectively, and was classified as other current assets on our Consolidated Balance Sheets. Changes in the fair value of these derivative instruments are classified as revenues on our Consolidated Statements of Operations. We recorded revenues and losses of zero and losses of $0.2 million related to LNG inventory—affiliate derivatives in the three months ended September 30, 2013 and 2012, respectively. We recorded losses of $0.4 million and revenues of $0.7 million related to LNG inventory—affiliate derivatives in the nine months ended September 30, 2013 and 2012, respectively.
	Service Agreements
	During the three months ended September 30, 2013 and 2012, we recorded general and administrative expense—affiliate of $40.6 million and $32.2 million, respectively, under the service agreements described below. During the nine months ended September 30, 2013 and 2012, we recorded general and administrative expense—affiliate of $88.2 million and $42.0 million, respectively, under the service agreements described below.
	We anticipate that prior to December 31, 2013, our general partner, which currently performs services under operation and maintenance agreements with Sabine Pass Liquefaction, Sabine Pass LNG and CTPL, will assign its rights and obligations under these agreements to Cheniere Investments.
	Cheniere Partners Services Agreement
	We have entered into a services agreement with Cheniere LNG Terminals, LLC ("Cheniere Terminals"), a wholly owned subsidiary of Cheniere, pursuant to which we pay Cheniere Terminals a quarterly non-accountable overhead reimbursement charge of $2.8 million (adjusted for inflation) for the provision of various general and administrative services for our benefit. In addition, we reimburse Cheniere Terminals for all audit, tax, legal and finance fees incurred by Cheniere Terminals that are necessary to perform the services under the agreement.
	Sabine Pass LNG O&M Agreement
	Sabine Pass LNG has entered into a long-term operation and maintenance agreement (the "Sabine Pass LNG O&M Agreement") with a wholly owned subsidiary of Cheniere pursuant to which we receive all necessary services required to operate and maintain the Sabine Pass LNG receiving terminal. Sabine Pass LNG is required to pay a fixed monthly fee of $130,000 (indexed for inflation) under the agreement, and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between Sabine Pass LNG and the counterparty at the beginning of each operating year. In addition, Sabine Pass LNG is required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses.
	Sabine Pass LNG MSA
	Sabine Pass LNG has entered into a long-term management services agreement (the "Sabine Pass LNG MSA") with Cheniere Terminals, pursuant to which Cheniere Terminals manages the operation of the Sabine Pass LNG receiving terminal, excluding those matters provided for under the Sabine Pass LNG O&M Agreement. Sabine Pass LNG is required to pay Cheniere Terminals a monthly fixed fee of $520,000 (indexed for inflation).
	Sabine Pass Liquefaction O&M Agreement
	In May 2012, Sabine Pass Liquefaction entered into an operation and maintenance agreement (the "Liquefaction O&M Agreement") with a wholly owned subsidiary of Cheniere and our general partner pursuant to which we receive all of the necessary services required to construct, operate and maintain the liquefaction facilities. Before the liquefaction facilities are operational, the services to be provided include, among other services, obtaining governmental approvals on behalf of Sabine Pass Liquefaction, 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, Sabine Pass Liquefaction is 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, Sabine Pass Liquefaction 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.
	Sabine Pass Liquefaction MSA
	In May 2012, Sabine Pass Liquefaction entered into a management services agreement (the "Liquefaction MSA") with a wholly owned subsidiary of Cheniere pursuant to which such subsidiary was appointed to manage the construction and operation of the liquefaction facilities, excluding those matters provided for under the Liquefaction O&M Agreement. The services to be provided include, among other services, exercising the day-to-day management of Sabine Pass Liquefaction's affairs and business, managing Sabine Pass Liquefaction's regulatory matters, managing bank and brokerage accounts and financial books and records of Sabine Pass Liquefaction's business and operations, and providing contract administration services for all contracts associated with the liquefaction facilities. Sabine Pass Liquefaction will pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, Sabine Pass Liquefaction pays a fixed monthly fee of $541,667 for services with respect to such Train.
	CTPL O&M Agreement
	In May 2013, CTPL entered into an amended long-term operation and maintenance agreement (the "CTPL O&M Agreement") with a wholly owned subsidiary of Cheniere pursuant to which we receive all necessary services required to operate and maintain the Creole Trail Pipeline. CTPL is required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses.
	CTPL MSA
	In May 2013, CTPL entered into a management services agreement (the "CTPL MSA") with a wholly owned subsidiary of Cheniere pursuant to which such subsidiary was appointed to manage the modification and operation of the Creole Trail Pipeline, excluding those matters provided for under the CTPL O&M Agreement. The services to be provided include, among other services, exercising the day-to-day management of CTPL's affairs and business, managing CTPL's regulatory matters, managing bank and brokerage accounts and financial books and records of CTPL's business and operations, and providing contract administration services for all contracts associated with the liquefaction facilities. CTPL pays a monthly fee equal to 3.0% of the capital expenditures to enable bi-directional natural gas flow on the Creole Trail Pipeline incurred in the previous month.
	Agreement to Fund Sabine Pass LNG's Cooperative Endeavor Agreements
	In July 2007, Sabine Pass LNG executed Cooperative Endeavor Agreements ("CEAs") with various Cameron Parish, Louisiana taxing authorities that allow them to collect certain annual property tax payments from Sabine Pass LNG in 2007 through 2016. This ten-year initiative represents an aggregate $25.0 million commitment and will make resources available to the Cameron Parish taxing authorities on an accelerated basis in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for Sabine Pass LNG's payments of annual ad valorem taxes, Cameron Parish will grant Sabine Pass LNG a dollar for dollar credit against future ad valorem taxes to be levied against the Sabine Pass LNG terminal starting in 2019. In September 2007, Sabine Pass LNG modified its TUA with Cheniere Marketing, pursuant to which Cheniere Marketing would pay Sabine Pass LNG additional TUA revenues equal to any and all amounts payable under the CEAs in exchange for a similar amount of credits against future TUA payments it would owe Sabine Pass LNG under its TUA starting in 2019. In June 2010, Cheniere Marketing assigned its TUA to Cheniere Investments and concurrently entered into a VCRA, allowing Cheniere Marketing to utilize Cheniere Investments' capacity under the TUA after the assignment. In July 2012, Cheniere Investments entered into an amended and restated VCRA with Cheniere Marketing in order for Cheniere Investments to utilize the capacity rights granted under the TURA during construction of the Liquefaction Project.
	On a consolidated basis, these advance tax payments were recorded to other assets, and payments from Cheniere Marketing that Sabine Pass LNG utilized to make the ad valorem tax payments were recorded as deferred revenue. As of September 30, 2013 we had $17.2 million of both other non-current assets and non-current deferred revenue—affiliate, and as of December 31, 2012, we had $14.7 million of both other non-current assets and non-current deferred revenue—affiliate in each case resulting from Sabine Pass LNG's ad valorem tax payments and the advance tax payments received from Cheniere Marketing, respectively.
	Contracts for Sale and Purchase of Natural Gas and LNG
	Sabine Pass LNG is able to sell and purchase natural gas and LNG under agreements with Cheniere Marketing. Under these agreements, Sabine Pass LNG purchases natural gas or LNG from Cheniere Marketing at a sales price equal to the actual purchase cost paid by Cheniere Marketing to suppliers of the natural gas or LNG, plus any third-party costs incurred by Cheniere Marketing in respect of the receipt, purchase, and delivery of the natural gas or LNG to the Sabine Pass LNG terminal.
	Sabine Pass LNG recorded $0.7 million of natural gas and LNG purchased from Cheniere Marketing under this agreement in the three months ended September 30, 2013 and 2012. Sabine Pass LNG recorded $2.5 million and $1.9 million of natural gas and LNG purchased from Cheniere Marketing under this agreement in the nine months ended September 30, 2013 and 2012, respectively.
	Sabine Pass LNG recorded $5.7 million and $2.8 million of natural gas sold to Cheniere Marketing under this agreement in the three months ended September 30, 2013 and 2012, respectively. Sabine Pass LNG recorded $8.6 million and $2.8 million of natural gas sold to Cheniere Marketing under this agreement in the nine months ended September 30, 2013 and 2012, respectively.
	Tug Boat Lease Sharing Agreement
	In connection with its tug boat lease, Sabine Pass Tug Services, LLC, a wholly owned subsidiary of Sabine Pass LNG ("Tug Services"), entered into a tug sharing agreement with Cheniere Marketing to provide its LNG cargo vessels with tug boat and marine services at the Sabine Pass LNG terminal. Tug Services recorded revenues—affiliate from Cheniere Marketing of $0.7 million pursuant to this agreement in each of the three months ended September 30, 2013 and 2012. Tug Services recorded revenues—affiliate from Cheniere Marketing of $2.1 million pursuant to this agreement in each of the nine months ended September 30, 2013 and 2012.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information and Disclosures of Non-Cash Transactions	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
Supplemental Cash Flow Information and Disclosures of Non-cash Transactions	'
	SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Nine Months Ended September 30,
		2013		2012
	Class B units issued in connection with the Creole Trail Pipeline Business acquisition	$	180,000	$	—
	LNG terminal costs funded with accounts payable and accrued liabilities (including amounts due to affiliates)	88,420		52,830
	Cash paid during the period for interest, net of amounts capitalized and deferred	56,428		77,140

Cash_Distributions_and_Net_Inc

Cash Distributions and Net Income (Loss) per Common Unit	9 Months Ended
	Sep. 30, 2013
CASH DISTRIBUTIONS AND NET INCOME (LOSS) PER COMMON UNIT [Abstract]	'
Cash Distributions and Net Income (Loss) per Common Unit	'
	CASH DISTRIBUTIONS AND NET INCOME (LOSS) PER COMMON UNIT
	Cash Distributions
	Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash (as defined in our partnership agreement). Generally, our available cash is our cash on hand at the end of a quarter less the amount of any reserves established by our general partner. All distributions paid to date have been made from operating surplus as defined in the partnership agreement. The following provides a summary of distributions paid by us during the nine months ended September 30, 2013:
													Total Distribution (in thousands)
	Date Paid		Period Covered by Distribution		Distribution Per Common Unit				Distribution Per Subordinated Unit				Common Units				Class B Units		Subordinated Units		General Partner Units
	February 14, 2013		October 1 - December 31, 2012		$	0.425			$	—			$	16,783			—		—		$	342
	May 15, 2013		January 1 - March 31, 2013		0.425				—				24,259				—		—		495
	August 15, 2013		April 1 - June 30, 2013		0.425				—				24,259				—		—		495
	The subordinated units will receive distributions only to the extent we have available cash above the initial quarterly distribution requirement for our common unitholders and general partner and certain reserves.
	In 2012, we issued and sold 133.3 million Class B units to Blackstone and Cheniere at a price of $15.00 per Class B unit, resulting in total gross proceeds of $2.0 billion. In connection with our purchase of the Creole Trail Pipeline Business in May 2013, we issued and sold 12.0 million Class B units to Cheniere at a price of $15.00 per Class B unit. The Class B units were issued at a discount to the market price of the common units into which they are convertible.  This discount totaling $2,130.0 million represents a beneficial conversion feature and is reflected as an increase in common and subordinated unitholders’ equity and a decrease in Class B unitholders’ equity to reflect the fair value of the Class B units at issuance on our consolidated statement of partners’ and owners' equity (deficit).  The beneficial conversion feature is considered a dividend that will be distributed ratably with respect to any Class B unit from its issuance date through its conversion date, resulting in an increase in Class B unitholders’ equity and a decrease in common and subordinated unitholders’ equity. We amortize the beneficial conversion feature assuming a conversion date of June 2017 and August 2017 for Cheniere’s and Blackstone’s Class B units, respectively, although actual conversion may occur prior to or after these assumed dates. We are amortizing the beneficial conversion feature over the original 60 month conversion schedule using the effective yield method with a weighted average effective yield of 943.1% per year and 958.0% per year for Cheniere’s and Blackstone’s Class B units, respectively. The impact of the beneficial conversion feature is also included in earnings per unit for the three and nine months ended September 30, 2013 and 2012.
	The following is a schedule by years, based on the capital structure as of September 30, 2013, of the anticipated impact to the capital accounts in connection with the amortization of the beneficial conversion feature (in thousands):
		Common Units				Class B Units				Subordinated Units
	2013	$	—			$	—			$	—
	2014	(2		)		6				(4		)
	2015	(241		)		813				(572		)
	2016	(32,023		)		107,979				(75,955		)
	2017	(538,538		)		1,815,883				(1,277,345		)
	The Class B units will mandatorily convert into common units on the first business day following the record date with respect to Cheniere Partners’ first distribution (the "Mandatory Conversion Date") after the earlier of the substantial completion date of Train 3 or August 9, 2017, although if a notice to proceed is given to Bechtel for Train 3 prior to August 9, 2017, the Mandatory Conversion Date will be the substantial completion date of Train 3. The notice to proceed was given to Bechtel on May 28, 2013. If the Class B units are not mandatorily converted by July 2019, the holders of the Class B units have the option to convert the Class B units into common units at that time.
	Net Income (Loss) per Common Unit
	Net income (loss) per common unit for a given period is based on the distributions that will be made to the unitholders with respect to the period plus an allocation of undistributed net income (loss) based on provisions of the partnership agreement, divided by the weighted average number of common units outstanding. The two class method dictates that net income (loss) for a period be reduced by the amount of available cash that will be distributed with respect to that period and that any residual amount representing undistributed net income be allocated to common unitholders and other participating unitholders to the extent that each unit may share in net income as if all of the net income for the period had been distributed in accordance with the partnership agreement. Undistributed income is allocated to participating securities based on the distribution waterfall for available cash specified in the partnership agreement. Undistributed losses (including those resulting from distributions in excess of net income) are allocated to common units and other participating securities on a pro rata basis based on provisions of the partnership agreement. Distributions are treated as distributed earnings in the computation of earnings per common unit even though cash distributions are not necessarily derived from current or prior period earnings.
	Under our partnership agreement, the incentive distribution rights ("IDRs") participate in net income (loss) only to the extent of the amount of cash distributions actually declared, thereby excluding the IDRs from participating in undistributed net income (loss). We did not allocate earnings or losses to IDR holders for the purpose of the two class method earnings per unit calculation for any of the periods presented. The following table provides a reconciliation of net income (loss) and the allocation of net income (loss) to the common units and the subordinated units for purposes of computing net income (loss) per unit (in thousands, except per unit data):
							Limited Partner Units
			Total				Common Units				Class B Units				Subordinated Units			General Partner			Creole Trail Pipeline Business
	Three Months Ended September 30, 2013
	Net loss		$	(98,109	)
	Declared distributions		24,754				24,259				—				—			495
	Assumed allocation of undistributed net loss		$	(122,863	)		(35,780		)		—				(84,865		)	(2,462		)	244
	Assumed allocation of net loss						$	(11,521	)		$	—			$	(84,865	)	$	(1,967	)	$	244
	Weighted average units outstanding						57,079				—				135,384
	Net loss per unit						$	(0.20	)		$	—			$	(0.63	)
	Three Months Ended September 30, 2012
	Net loss		$	(51,370	)
	Declared distributions		17,125				16,783				—				—			342
	Amortization of beneficial conversion feature of Class B units		—				(2,971		)		14,888				(11,917		)	—
	Assumed allocation of undistributed net loss		$	(68,495	)		(12,467		)		—				(42,744		)	(4,336		)	(8,948		)
	Assumed allocation of net income (loss)						$	1,345			$	14,888			$	(54,661	)	$	(3,994	)	$	(8,948	)
	Weighted average units outstanding						31,997				54,710				135,384
	Net income (loss) per unit						$	0.04			$	0.27			$	(0.40	)
	Nine Months Ended September 30, 2013
	Net loss		$	(196,851	)
	Declared distributions		74,261				72,776				—				—			1,485
	Assumed allocation of undistributed net loss		$	(271,112	)		(73,521		)		—				(174,382		)	(5,059		)	(18,150		)
	Assumed allocation of net income (loss)						$	(745	)		$	—			$	(174,382	)	$	(3,574	)	$	(18,150	)
	Weighted average units outstanding						53,277				—				135,384
	Net income (loss) per unit						$	(0.01	)		$	—			$	(1.29	)
	Nine Months Ended September 30, 2012
	Net loss		$	(106,818	)
	Declared distributions		44,376				43,488				—				—			888
	Amortization of beneficial conversion feature of Class B units		—				(3,863		)		19,625				(15,762		)	—
	Assumed allocation of undistributed net loss		$	(151,194	)		(28,278		)		—				(96,948		)	(5,765		)	(20,203		)
	Assumed allocation of net income (loss)						$	11,347			$	19,625			$	(112,710	)	$	(4,877	)	$	(20,203	)
	Weighted average units outstanding						31,449				19,181				135,384
	Net income (loss) per unit						$	0.36			$	1.02			$	(0.83	)

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2013
Property, Plant and Equipment [Abstract]	'
Schedule of capitalized terminal costs and fixed assets	'
	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		September 30,			December 31,
		2013			2012
	LNG terminal costs
	LNG terminal	$	2,224,364		$	2,224,230
	LNG terminal construction-in-process	3,694,355			1,228,647
	LNG site and related costs, net	150			156
	Accumulated depreciation	(276,960		)	(234,349		)
	Total LNG terminal costs, net	5,641,909			3,218,684
	Fixed assets
	Computer and office equipment	474			368
	Vehicles	884			704
	Machinery and equipment	1,490			1,473
	Other	837			760
	Accumulated depreciation	(2,722		)	(2,397		)
	Total fixed assets, net	963			908
	Property, plant and equipment, net	$	5,642,872		$	3,219,592

Financial_Instruments_Financia

Financial Instruments Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	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, 2013 and December 31, 2012, which are classified as other current assets, other current liabilities, other non-current assets and other non-current liabilities in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		30-Sep-13																31-Dec-12
		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	$	—			$	219			$	—			$	219			$	—			$	232			$	—	$	232
	Fuel Derivatives (liability)	—				(227		)		—				(227		)		—				(98		)		—		(98		)
	Interest Rate Derivatives asset (liability)	—				56,039				—				56,039				—				(26,424		)		—		(26,424		)
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]	'
	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives recorded in revenues on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	LNG Inventory Derivatives gain (loss)	$	—			$	(228	)		$	(442	)		$	697
	The following table (in thousands) shows the changes in the fair value and settlements of our Fuel Derivatives and LNG Inventory Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	LNG Inventory Derivatives gain	$	201			$	—			$	976			$	—
	Fuel Derivatives gain (loss) (1)	(55		)		287				(3		)		(288		)
	The following table (in thousands) shows the changes in the fair value of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	Interest Rate Derivatives - Not Designated gain (loss)	$	(22,481	)		$	—			$	60,707			$	—
	Balance Sheet
Schedule of Notional Amounts of Outstanding Derivative Positions	'
	At September 30, 2013, Sabine Pass Liquefaction 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	million		$	2.9	billion		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
	Interest Rate Derivatives - Not Designated		—				$	671	million		5-Jun-13		28-May-20		2.05%		One-month LIBOR
Schedule of Interest Rate Derivatives	'
	The following table (in thousands) shows the fair value of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		September 30, 2013				December 31, 2012
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	64,309			$	—
	Interest Rate Derivatives - Designated		Non-current derivative liabilities		—				21,290
	Interest Rate Derivatives - Not Designated		Other current liabilities		8,270				—
	Interest Rate Derivatives - Not Designated		Non-current derivative liabilities		—				5,134
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 OCI and AOCI for the nine months ended September 30, 2013 and 2012:
		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
		2013				2012				2013				2012				2013				2012
	Interest Rate Derivatives - Designated	$	21,297			$	(29,676	)		$	—			$	—			$	(5,806	)		$	—
	Interest Rate Derivatives - Settlements	(30		)		—				—				—				(167		)		—
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the three months ended September 30, 2013 and 2012:
		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
		2013				2012				2013				2012				2013				2012
	Interest Rate Derivatives - Designated	$	—			$	(29,676	)		$	—			$	—			$	—			$	—
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	commodity and interest rate derivatives are presented on a net basis on our Consolidated Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized					Gross Amounts Offset in the Consolidated Balance Sheet				Net Amounts Presented in the Consolidated Balance Sheet				Gross Amounts Not Offset in the Consolidated Balance Sheet
	Offsetting Derivative Assets (Liabilities)															Derivative Instrument				Cash Collateral Received (Paid)				Net Amount
	As of September 30, 2013:
	Fuel Derivatives		$	(227	)			$	(227	)		$	—			$	—			$	—			$	—
	LNG Inventory Derivatives		219					—				219				—				—				219
	Interest Rate Derivatives - Not Designated		64,309					—				64,309				—				—				64,309
	Interest Rate Derivatives - Not Designated		(8,270		)			—				(8,270		)		—				—				(8,270		)
	As of December 31, 2012:					—
	Fuel Derivatives		(98		)			(98		)		—				—				—				—
	LNG Inventory Derivatives		232					—				232				—				—				232
	Interest Rate Derivatives - Designated		(21,290		)			—				(21,290		)		—				—				(21,290		)
	Interest Rate Derivatives - Not Designated		(5,134		)			—				(5,134		)		—				—				(5,134		)
Fair Value, by Balance Sheet Grouping	'
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			September 30, 2013				December 31, 2012
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	219			$	232
	Fuel Derivatives liability	Prepaid expenses and other			(227		)		(98		)

Accrued_Liabilities_Accrued_Li

Accrued Liabilities Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2013
Payables and Accruals [Abstract]	'
Schedule of Accrued Liabilities	'
	As of September 30, 2013 and December 31, 2012, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		September 30,		December 31,
		2013		2012
	Interest and related debt fees	$	97,758	$	16,327
	Affiliate	51,419		5,744
	LNG liquefaction costs	33,589		26,131
	LNG terminal costs	1,650		977
	Other	8,791		4,413
	Total accrued liabilities (including affiliate)	$	193,207	$	53,592

LongTerm_Debt_LongTerm_Debt_Ta

Long-Term Debt Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Schedule of Long-term debt	'
	As of September 30, 2013 and December 31, 2012, our long-term debt consisted of the following (in thousands):
		September 30,			December 31,
		2013			2012
	Long-term debt
	2016 Notes	$	1,665,500		$	1,665,500
	2020 Notes	420,000			420,000
	2021 Sabine Pass Liquefaction Senior Notes	2,000,000			—
	2023 Sabine Pass Liquefaction Senior Notes	1,000,000			—
	2012 Liquefaction Credit Facility	—			100,000
	2013 Liquefaction Credit Facilities	100,000			—
	CTPL Credit Facility	400,000			—
	Total long-term debt	5,585,500			2,185,500
	Long-term debt premium (discount)
	2016 Notes	(14,866		)	(18,387		)
	2021 Sabine Pass Liquefaction Senior Notes	11,897			—
	CTPL Credit Facility	(8,336		)	—
	Total long-term debt, net	$	5,574,195		$	2,167,113

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information and Disclosures of Non-cash Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Supplemental Cash Flow Disclosures	'
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Nine Months Ended September 30,
		2013		2012
	Class B units issued in connection with the Creole Trail Pipeline Business acquisition	$	180,000	$	—
	LNG terminal costs funded with accounts payable and accrued liabilities (including amounts due to affiliates)	88,420		52,830
	Cash paid during the period for interest, net of amounts capitalized and deferred	56,428		77,140

Cash_Distribution_and_Net_Inco

Cash Distribution and Net Income (Loss) per Common Unit (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Schedule of Distributions Made to Members or Limited Partners, by Distribution	'
	The following provides a summary of distributions paid by us during the nine months ended September 30, 2013:
													Total Distribution (in thousands)
	Date Paid		Period Covered by Distribution		Distribution Per Common Unit				Distribution Per Subordinated Unit				Common Units				Class B Units		Subordinated Units		General Partner Units
	February 14, 2013		October 1 - December 31, 2012		$	0.425			$	—			$	16,783			—		—		$	342
	May 15, 2013		January 1 - March 31, 2013		0.425				—				24,259				—		—		495
	August 15, 2013		April 1 - June 30, 2013		0.425				—				24,259				—		—		495
Schedule of Anticipated Beneficial Conversion Feature impact to Capital Accounts	'
	The following is a schedule by years, based on the capital structure as of September 30, 2013, of the anticipated impact to the capital accounts in connection with the amortization of the beneficial conversion feature (in thousands):
		Common Units				Class B Units				Subordinated Units
	2013	$	—			$	—			$	—
	2014	(2		)		6				(4		)
	2015	(241		)		813				(572		)
	2016	(32,023		)		107,979				(75,955		)
	2017	(538,538		)		1,815,883				(1,277,345		)
Schedule of Weighted Average Number of Shares	'
	The following table provides a reconciliation of net income (loss) and the allocation of net income (loss) to the common units and the subordinated units for purposes of computing net income (loss) per unit (in thousands, except per unit data):
							Limited Partner Units
			Total				Common Units				Class B Units				Subordinated Units			General Partner			Creole Trail Pipeline Business
	Three Months Ended September 30, 2013
	Net loss		$	(98,109	)
	Declared distributions		24,754				24,259				—				—			495
	Assumed allocation of undistributed net loss		$	(122,863	)		(35,780		)		—				(84,865		)	(2,462		)	244
	Assumed allocation of net loss						$	(11,521	)		$	—			$	(84,865	)	$	(1,967	)	$	244
	Weighted average units outstanding						57,079				—				135,384
	Net loss per unit						$	(0.20	)		$	—			$	(0.63	)
	Three Months Ended September 30, 2012
	Net loss		$	(51,370	)
	Declared distributions		17,125				16,783				—				—			342
	Amortization of beneficial conversion feature of Class B units		—				(2,971		)		14,888				(11,917		)	—
	Assumed allocation of undistributed net loss		$	(68,495	)		(12,467		)		—				(42,744		)	(4,336		)	(8,948		)
	Assumed allocation of net income (loss)						$	1,345			$	14,888			$	(54,661	)	$	(3,994	)	$	(8,948	)
	Weighted average units outstanding						31,997				54,710				135,384
	Net income (loss) per unit						$	0.04			$	0.27			$	(0.40	)
	Nine Months Ended September 30, 2013
	Net loss		$	(196,851	)
	Declared distributions		74,261				72,776				—				—			1,485
	Assumed allocation of undistributed net loss		$	(271,112	)		(73,521		)		—				(174,382		)	(5,059		)	(18,150		)
	Assumed allocation of net income (loss)						$	(745	)		$	—			$	(174,382	)	$	(3,574	)	$	(18,150	)
	Weighted average units outstanding						53,277				—				135,384
	Net income (loss) per unit						$	(0.01	)		$	—			$	(1.29	)
	Nine Months Ended September 30, 2012
	Net loss		$	(106,818	)
	Declared distributions		44,376				43,488				—				—			888
	Amortization of beneficial conversion feature of Class B units		—				(3,863		)		19,625				(15,762		)	—
	Assumed allocation of undistributed net loss		$	(151,194	)		(28,278		)		—				(96,948		)	(5,765		)	(20,203		)
	Assumed allocation of net income (loss)						$	11,347			$	19,625			$	(112,710	)	$	(4,877	)	$	(20,203	)
	Weighted average units outstanding						31,449				19,181				135,384
	Net income (loss) per unit						$	0.36			$	1.02			$	(0.83	)

Organization_and_Nature_of_Ope1

Organization and Nature of Operations (Details) (USD $)

9 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Class B Unit [Member]

Creole Trail Pipeline Business [Domain]

Cheniere Energy Partners, LP [Member]

Cheniere Energy Partners, LP [Member]

Cheniere Energy Partners, LP [Member]

Class B Unit [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass Liquefaction [Member]

Maximum [Member]

Class B Unit [Member]

Cheniere Energy Partners, LP [Member]

bcf

trains

Sabine Pass LNG, LP [Member]

m3

Organization and nature of operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Storage Capacity

'

'

'

'

'

'

'

'

16.9

'

'

Regasification capacity

'

'

'

'

'

'

'

'

4

'

'

Volume of Vessel

'

'

'

'

'

'

'

'

'

'

265,000

Number of Liquefaction LNG Trains

'

'

'

'

'

'

'

'

'

6

'

Train nominal capacity

'

'

'

'

'

'

'

'

'

4,500,000

'

Business Acquisition, Cost of Acquired Entity, Purchase Price

'

'

'

$480,000,000

'

'

'

'

'

'

'

Reimbursement of costs incurred prior to acquisition closing date

'

'

'

13,900,000

'

'

'

'

'

'

'

Sale of common and general partner units

375,897,000

'

0

'

'

'

12,000,000

'

'

'

'

Price Per Common Unit

'

'

'

'

'

'

'

$15

'

'

'

Proceeds from sale Of Class B Units

0

1,387,560,000

[1]

'

'

0

180,000,000

'

'

'

'

'

Business Acquisition, Cost of Acquired Entity, Cash Paid

$313,900,000

'

'

'

'

'

'

'

'

'

'

[1]

Retrospectively adjusted as discussed in Note 2.

Restricted_Cash_and_Cash_Equiv1

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

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

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 Creole Trail Pipeline LP [Member]

2016 Notes [Member]

2016 Notes [Member]

2020 Notes [Member]

2020 Notes [Member]

2020 Notes [Member]

2020 Notes [Member]

Liquefaction Credit Facility [Member]

Senior Secured Notes Due 2021 [Member]

Senior Secured Notes due 2023 [Member]

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

Creole Trail Pipeline Credit Facility [Member]

Payment of Liabilities [Member]

Payment of Liabilities [Member]

Payment For Project [Member]

Payment For Project [Member]

Senior Notes Interest Payments [Member]

Senior Notes Interest Payments [Member]

Debt Service Reserve Fund [Member]

Debt Service Reserve Fund [Member]

Senior Notes [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]

Sabine Pass LNG, LP [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Cheniere Creole Trail Pipeline LP [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Rate

Senior Notes [Member]

Senior Notes [Member]

Debt Service Reserve Fund [Member]

Debt Service Reserve Fund [Member]

Debt Service Reserve Fund [Member]

Debt Service Reserve Fund [Member]

Restricted Cash and Cash Equivalents Items [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

$1,665,500,000

$1,665,500,000

'

'

$420,000,000

$420,000,000

'

$2,000,000,000

$1,000,000,000

$1,000,000,000

'

$400,000,000

'

'

'

'

Debt instrument stated rate (percent)

'

'

'

'

'

'

'

'

7.50%

7.50%

6.50%

6.50%

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument fixed charge coverage ratio

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current restricted cash and cash equivalents

210,076,000

92,519,000

53,000,000

17,400,000

'

'

'

23,500,000

'

'

'

'

'

'

'

'

'

'

'

'

133,500,000

75,100,000

'

'

Non-current restricted cash and cash equivalents

828,360,000

272,425,000

'

'

76,100,000

76,100,000

'

87,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

665,100,000

196,300,000

Maximum borrowing capacity on credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3,600,000,000

'

'

'

$5,900,000,000

'

'

'

'

'

Property_Plant_and_Equipment_C

Property, Plant and Equipment - Capitalized Costs and Fixed Assets (Details) (USD $)

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sabine Pass LNG terminal [Member]

Sabine Pass LNG terminal [Member]

Sabine Pass LNG terminal [Member]

Sabine Pass LNG terminal [Member]

LNG terminal [Member]

LNG terminal [Member]

LNG terminal construction-in-process [Member]

LNG terminal construction-in-process [Member]

LNG site and related costs, net [Member]

LNG site and related costs, net [Member]

LNG terminal costs [Member]

LNG terminal costs [Member]

Fixed assets [Member]

Fixed assets [Member]

Computer and Office Equipment

Computer and Office Equipment

Vehicles

Vehicles

Machinery and Equipment

Machinery and Equipment

Other

Other

The Sabine Pass Liquefaction Project [Member]

The Sabine Pass Liquefaction Project [Member]

The Sabine Pass Liquefaction Project [Member]

The Sabine Pass Liquefaction Project [Member]

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment, gross

'

'

'

'

'

'

'

$2,224,364,000

$2,224,230,000

$3,694,355,000

$1,228,647,000

$150,000

$156,000

'

'

'

'

$474,000

$368,000

$884,000

$704,000

$1,490,000

$1,473,000

$837,000

$760,000

'

'

'

'

Accumulated depreciation

'

'

'

'

'

'

'

'

'

'

'

'

'

-276,960,000

-234,349,000

-2,722,000

-2,397,000

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment, net

5,642,872,000

'

3,219,592,000

'

'

'

'

'

'

'

'

'

'

5,641,909,000

3,218,684,000

963,000

908,000

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation expense

43,150,000

43,135,000

[1]

'

14,400,000

14,400,000

42,800,000

42,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized interest expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30,200,000

$14,000,000

$125,000,000

$14,000,000

[1]

Retrospectively adjusted as discussed in Note 2.

Financial_Instruments_Fair_Val

Financial Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	$0	$0
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	0	0
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	219	232
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	219	232
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	219	232
Fuel Derivatives [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	0	0
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fuel Derivatives liability	0	0
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fuel Derivatives liability	0	0
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fuel Derivatives liability	-227	-98
Fuel Derivatives [Member] | Prepaid Expenses And Other [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fuel Derivatives liability	-227	-98
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	0	0
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	'	-26,424
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	0	0
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	'	-26,424
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	-8,270	-5,134
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	56,039	'
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Net	$56,039	'

Financial_Instruments_Fair_Val1

Financial Instruments - Fair Value of Financial Instruments by Balance Sheet Location (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'	'
Collateral deposited	$921,701	$890,609
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
LNG Inventory Derivative assets	$219,000	$232,000

Financial_Instruments_Fair_Val2

Financial Instruments - Fair Value and Settlements of Derivatives (Details) (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'		'	'
Derivative gain (loss), net	($22,335)	$287	[1]	$55,706	($288)	[1]
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member]	'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'		'	'
Derivative gain (loss), net	0	-228		-442	697
Sabine Pass Liquefaction [Member] | LNG Inventory Derivatives [Member]	'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'		'	'
Derivative gain (loss), net	201	0		976	0
Sabine Pass LNG, LP [Member] | Fuel Derivatives [Member]	'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'		'	'
Derivative gain (loss), net	($55)	$287		($3)	($288)
[1]	Retrospectively adjusted as discussed in Note 2.

Financial_Instruments_Notional

Financial Instruments - Notional Amounts of Derivative Instruments (Details) (Interest Rate Contract [Member], Not Designated as Hedging Instrument [Member], USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Derivative [Line Items]	'
Debt Instrument, Description of Variable Rate Basis	'One-month LIBOR
Sabine Pass Liquefaction [Member]	'
Derivative [Line Items]	'
Notional Amount of Interest Rate Derivatives	0
Derivative instrument average fixed rate (percent)	1.98%
Sabine Pass Liquefaction [Member] | Maximum [Member]	'
Derivative [Line Items]	'
Notional Amount of Interest Rate Derivatives	2,900
Effective Date June 5, 2013 [Domain]	'
Derivative [Line Items]	'
Debt Instrument, Description of Variable Rate Basis	'One-month LIBOR
Effective Date June 5, 2013 [Domain] | Sabine Pass Liquefaction [Member]	'
Derivative [Line Items]	'
Derivative instrument average fixed rate (percent)	2.05%
Effective Date June 5, 2013 [Domain] | Sabine Pass Liquefaction [Member] | Maximum [Member]	'
Derivative [Line Items]	'
Notional Amount of Interest Rate Derivatives	671

Financial_Instruments_Fair_Val3

Financial Instruments - Fair Value of Interest Rate Derivatives by Balance Sheet Location (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'	'
Collateral deposited	$921,701	$890,609
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Liabilities, at Fair Value	0	21,290,000
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Non-current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Liabilities, at Fair Value	0	5,134,000
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Liabilities, at Fair Value	8,270,000	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Noncurrent Derivative Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Interest Rate Derivative Assets, at Fair Value	$64,309,000	$0

Financial_Instruments_Interest

Financial Instruments - Interest Rate Derivatives Market Adjustments (Details) (Interest Rate Contract [Member], USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Designated as Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	$0	($29,676)	$21,297	($29,676)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0	0	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	-5,806	0
Gain (Loss) on Settlement of Derivative Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	'	'	-30	0
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	'	'	($167)	$0

Financial_Instruments_Changes_

Financial Instruments - Changes in Fair Value of De-Designated Interest Rate Derivatives (Details) (Not Designated as Hedging Instrument [Member], Interest Rate Contract [Member], USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]	'	'	'	'
Derivative [Line Items]	'	'	'	'
Increase (Decrease) in Fair Value of Derivative Instruments, Not Designated as Hedging Instruments	($22,481)	$0	$60,707	$0

Financial_Instruments_Derivati

Financial Instruments - Derivative Gross Presentation on Consolidated Balance Sheets (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fuel Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	($227)	($98)
Derivative Liability, Fair Value, Amount Offset Against Collateral	-227	-98
Derivative Liability, Fair Value, Net	0	0
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
LNG Inventory Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	219	232
Derivative Asset, Fair Value, Amount Offset Against Collateral	0	0
Derivative Asset, Fair Value, Net	219	232
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-8,270	-5,134
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0
Derivative Liability, Fair Value, Net	-8,270	-5,134
Derivative Asset, Fair Value, Gross Asset	64,309	'
Derivative Asset, Fair Value, Amount Offset Against Collateral	0	'
Derivative Asset, Fair Value, Net	64,309	'
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	'	-21,290
Derivative Liability, Fair Value, Amount Offset Against Collateral	'	0
Derivative Liability, Fair Value, Net	'	-21,290
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	'	0
Derivative, Collateral, Right to Reclaim Cash	'	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Net	56,039	'
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Net	'	($26,424)

Financial_Instruments_Fair_Val4

Financial Instruments - Fair Value of Other Financial Instruments (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
2016 Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	$1,650,634	$1,647,113
2016 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	1,811,570	1,824,177
2020 Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	420,000	420,000
2020 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	425,250	437,850
2021 Sabine Pass Liquefaction Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	2,011,897	0
2021 Sabine Pass Liquefaction 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	1,951,540	0
Sabine Pass Liquefaction Notes due 2023 [Member] [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Lines of Credit, Fair Value Disclosure	1,000,000	0
Sabine Pass Liquefaction Notes due 2023 [Member] [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	952,500	0
Liquefaction Credit Facility [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Lines of Credit, Fair Value Disclosure	0	100,000
Liquefaction Credit Facility [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	100,000
2013 Sabine Pass Liquefaction Credit Facility [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Lines of Credit, Fair Value Disclosure	100,000	0
2013 Sabine Pass Liquefaction Credit Facility [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	100,000	0
Creole Trail Pipeline Credit Facility [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Lines of Credit, Fair Value Disclosure	391,665	0
Creole Trail Pipeline Credit Facility [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	$400,000	$0

Accrued_Liabilities_Accrued_Li1

Accrued Liabilities Accrued Liabilities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Payables and Accruals [Abstract]	'	'
Interest and related debt fees	$97,758	$16,327
Due to Affiliate, Current	51,419	5,744
Affiliate	52,474	7,562
LNG liquefaction costs	33,589	26,131
LNG terminal costs	1,650	977
Other	8,791	4,413
Total accrued liabilities (including affiliate)	$193,207	$53,592

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-term Debt (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Jul. 31, 2012

Sep. 30, 2013

2016 Notes [Member]

2016 Notes [Member]

2021 Sabine Pass Liquefaction Notes [Member]

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

Creole Trail Pipeline Credit Facility [Member]

Creole Trail Pipeline Credit Facility [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Cheniere Creole Trail Pipeline LP [Member]

Cheniere Creole Trail Pipeline LP [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Credit Facility [Domain]

Credit Facility [Domain]

2016 Notes [Member]

2016 Notes [Member]

Creole Trail Pipeline Credit Facility [Member]

Creole Trail Pipeline Credit Facility [Member]

2021 Sabine Pass Liquefaction Notes [Member]

2021 Sabine Pass Liquefaction Notes [Member]

2021 Sabine Pass Liquefaction Notes [Member]

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Liquefaction Credit Facility [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

2016 Notes [Member]

2016 Notes [Member]

2020 Notes [Member]

2020 Notes [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amortization Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'18 years 0 months

'18 years 0 months

Long Term Debt, Excluding Current Maturities (Including Related Parties)

$5,585,500,000

$2,185,500,000

'

'

'

'

'

'

'

'

$400,000,000

$0

$2,000,000,000

$0

'

$1,000,000,000

$0

$0

$100,000,000

$100,000,000

$0

$1,665,500,000

$1,665,500,000

$420,000,000

$420,000,000

'

'

Debt Instrument, Face Amount

'

'

'

'

2,000,000,000

1,000,000,000

'

'

1,665,500,000

1,665,500,000

400,000,000

'

'

'

2,000,000,000

'

'

'

'

'

'

'

'

420,000,000

420,000,000

'

'

Debt Instrument, Unamortized Discount

'

'

-14,866,000

-18,387,000

'

'

-8,336,000

0

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Premium

'

'

'

'

'

'

'

'

'

'

'

'

11,897,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt, net of discount

$5,574,195,000

$2,167,113,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

4 Months Ended

1 Months Ended

4 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

28-May-13

Jul. 31, 2012

Jul. 31, 2012

Sep. 30, 2013

Jul. 31, 2012

Jul. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Apr. 30, 2013

Jul. 31, 2012

Sep. 30, 2013

Aug. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

2016 Notes [Member]

2016 Notes [Member]

2021 Sabine Pass Liquefaction Notes [Member]

Creole Trail Pipeline Credit Facility [Member]

Creole Trail Pipeline Credit Facility [Member]

Creole Trail Pipeline Credit Facility - LIBOR Loans [Member]

Credit Facility [Domain]

Credit Facility [Domain]

Credit Facility [Domain]

Credit Facility [Domain]

Credit Facility [Domain]

Construction [Member]

Operations [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Cheniere Creole Trail Pipeline LP [Member]

Cheniere Creole Trail Pipeline LP [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]

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]

Debt Service Reserve Fund [Member]

Debt Service Reserve Fund [Member]

Issuance of Debt [Member]

Issuance of Debt [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

Liquifaction Credit Facility - LIBOR Loans [Member]

2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]

Liquifaction Credit Facility - LIBOR Loans [Member]

Liquifaction Credit Facility - LIBOR Loans [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

Sabine Pass Liquefaction Senior Notes [Domain]

Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

Liquefaction Credit Facility [Member]

Senior Secured Notes Due 2021 [Member]

Creole Trail Pipeline Credit Facility [Member]

2016 Notes [Member]

2016 Notes [Member]

2020 Notes [Member]

2020 Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass Liquefaction Notes due 2023 [Member] [Member]

Senior Secured Notes Due 2021 [Member]

Construction [Member]

Operations [Member]

Construction [Member]

Operations [Member]

Rate

Rate

2020 Notes [Member]

2020 Notes [Member]

2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]

2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]

2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]

2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

$1,000,000,000

'

'

$2,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,000,000,000

'

$400,000,000

$1,665,500,000

$1,665,500,000

'

'

'

'

'

'

$420,000,000

$420,000,000

'

'

$1,000,000,000

$500,000,000

'

'

'

'

Debt Instrument, Unamortized Discount

'

'

'

'

'

'

-14,866,000

-18,387,000

'

-8,336,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Maturity Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Jul-19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument stated rate (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.63%

'

'

'

'

'

'

'

7.50%

7.50%

6.50%

6.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption of Debt Instrument, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

'

'

Redemption Premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.065

'

'

'

'

'

'

'

'

'

Percentage if 2020 Notes Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

'

'

'

'

'

'

'

'

'

Debt instrument fixed charge coverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.25

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity on credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,900,000,000

'

'

'

3,600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-current restricted cash and cash equivalents

828,360,000

'

828,360,000

'

272,425,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

87,200,000

'

'

'

'

'

'

'

'

'

'

'

76,100,000

76,100,000

'

'

'

'

'

'

Percentage of Debt Hedged by Interest Rate Derivatives

'

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution made during the period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

93,000,000

36,200,000

242,100,000

182,900,000

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Description of Variable Rate Basis

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'LIBOR

'LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument basis spread

'

'

'

'

'

'

'

'

'

'

'

3.25%

'

'

'

'

'

3.50%

3.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.30%

2.30%

3.00%

3.25%

Upfront fee required under Liquefaction Credit Facility

'

'

'

'

'

'

'

'

'

'

'

'

144,000,000

'

178,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee as a percentage of LIBOR loans (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

40.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amortization Period

'

'

'

'

'

'

'

'

'

'

'

'

'18 years 0 months

'

'18 years 0 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Increase (Decrease) for Period, Net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on early extinguishment of debt

$0

$0

[1]

($80,510,000)

$0

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Retrospectively adjusted as discussed in Note 2.

Description_of_Equity_Interest1

Description of Equity Interests (Details) (USD $)

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

28-May-13

Sep. 30, 2013

Sep. 30, 2013

Class B Unit [Member]

Common Units

Common Units

Common Units

Common Units

General Partner [Member]

General Partner [Member]

General Partner [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Cheniere Energy Partners, LP [Member]

Minimum [Member]

Maximum [Member]

Blackstone CQP Holdco LP [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Class B Unit [Member]

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions Per General Partnership Unit Outstanding

'

'

'

'

'

'

$0.02

'

'

'

'

'

'

'

Incentive Distribution, Distribution Per Unit

'

'

'

'

'

'

'

15.00%

50.00%

'

'

'

'

'

Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit

'

'

$0.43

$0.43

$0.43

$0.43

'

'

'

'

'

'

'

'

Proceeds from Issuance or Sale of Equity

'

'

'

'

'

'

'

'

'

'

$1,500,000,000

$200,000,000

$500,000,000

'

Sale of common and general partner units

$375,897,000

'

'

'

'

'

$11,122,000

'

'

$0

'

'

'

$12,000,000

Partnership Units, Conversion Ratio, Quarterly Compounded Rate

'

3.50%

'

'

'

'

'

'

'

'

'

'

'

'

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended			9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2013	Sep. 30, 2012		Dec. 31, 2012
Related Party Transaction [Line Items]	'	'		'	'		'
Advances to Affiliate Current	$25,737,000	'		$25,737,000	'		$4,987,000
Operating Costs and Expenses	23,553,000	6,395,000	[1]	52,751,000	20,063,000	[1]	'
Revenuesbaffiliate	800,000	3,929,000	[1]	2,140,000	6,973,000	[1]	'
Derivative gain (loss), net	-22,335,000	287,000	[1]	55,706,000	-288,000	[1]	'
General and Administrative Expense Related Parties	42,239,000	36,871,000	[1]	101,998,000	48,745,000	[1]	'
Service Agreements [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
General and Administrative Expense Related Parties	40,600,000	32,200,000		88,200,000	42,000,000		'
Cooperative Endeavor Agreements [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Aggregate commitment under the Agreement	25,000,000	'		25,000,000	'		'
Sabine Pass Tug Services, LLC [Member] | Tug Boat Lease Sharing Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Revenuesbaffiliate	700,000	700,000		2,100,000	2,100,000		'
Cheniere Energy Investments, LLC [Member] | LNG Lease Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Liquefied Natural Gas Inventory	75,000	'		75,000	'		1,369,000
LNG inventory related party	200,000	'		200,000	'		4,420,000
LNG inventory related party LCM adjustments recognized	0	-100,000		0	500,000		'
Cheniere Energy Investments, LLC [Member] | LNG Terminal Capacity Agreements [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Proceeds (Payments) of Gross Margin Earned, Percentage	'	'		80.00%	'		'
Revenuesbaffiliate	'	3,200,000		0	4,900,000		'
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Derivative gain (loss), net	0	-228,000		-442,000	697,000		'
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member] | LNG Lease Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
LNG Inventory Derivative assets	0	'		0	'		200,000
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member] | Revenues [Member] | LNG Lease Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Derivative, Gain (Loss) on Derivative, Net	0	200,000		-400,000	700,000		'
Cheniere Creole Trail Pipeline LP [Member] | Management Services Agreement [Member] | Cheniere Energy, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Proceeds (Payments) Of Capital Expenditures Incurred	'	'		3.00%	'		'
Sabine Pass Liquefaction [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Operating Costs and Expenses	14,400,000	'		27,300,000	'		'
Sabine Pass Liquefaction [Member] | Operation and Maintenance Agreement [Member] | Cheniere Energy, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Related Party Transaction, Committed Monthly Fee	83,333	'		83,333	'		'
Proceeds (Payments) Of Capital Expenditures Incurred	'	'		0.60%	'		'
Sabine Pass Liquefaction [Member] | Management Services Agreement [Member] | Cheniere Energy, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Related Party Transaction, Committed Monthly Fee	541,667	'		541,667	'		'
Proceeds (Payments) Of Capital Expenditures Incurred	'	'		2.40%	'		'
Sabine Pass Liquefaction [Member] | LNG Sale and Purchase Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Purchase Commitment, Excess And Uncommitted LNG Produced	'	'		104,000,000	'		'
Sabine Pass Liquefaction [Member] | Profit Category One [Member] | LNG Sale and Purchase Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Purchase Commitment, Excess And Uncommitted LNG Produced	'	'		36,000,000	'		'
Incremental LNG Volume, Purchase Price Percentage	'	'		115.00%	'		'
Incremental LNG Volume, Purchase Price Per MMBtu	'	'		3	'		'
Sabine Pass Liquefaction [Member] | Profit Category Two [Member] | LNG Sale and Purchase Agreement [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Proceeds (Payments) of Gross Margin Earned, Percentage	'	'		20.00%	'		'
Purchase Commitment, Excess And Uncommitted LNG Produced	'	'		68,000,000	'		'
Sabine Pass Liquefaction [Member] | LNG Inventory Derivatives [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Derivative gain (loss), net	201,000	0		976,000	0		'
Sabine Pass LNG, LP [Member] | Operation and Maintenance Agreement [Member] | Cheniere Energy, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Related Party Transaction, Committed Monthly Fee	130,000	'		130,000	'		'
Related Party Transaction, Bonus Percentage Entitled Upon Meeting Certain Criteria	50.00%	'		50.00%	'		'
Sabine Pass LNG, LP [Member] | Management Services Agreement [Member] | Cheniere LNG Terminals, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Related Party Transaction, Committed Monthly Fee	520,000	'		520,000	'		'
Sabine Pass LNG, LP [Member] | Contracts for Sale and Purchase of Natural Gas and LNG [Member] | Natural Gas [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Revenuesbaffiliate	5,700,000	2,800,000		8,600,000	2,800,000		'
Sabine Pass LNG, LP [Member] | Contracts for Sale and Purchase of Natural Gas and LNG [Member] | Natural Gas And Liquefied Natural Gas [Member] | Cheniere Energy, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Related Party Transaction, Purchases from Related Party	700,000	700,000		2,500,000	1,900,000		'
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member] | Sabine Pass Liquefaction [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Regasification capacity	2	'		2	'		'
Related Party Transactions, Commitments, Annual Reservation Fee Payment	250,000,000	'		'	'		'
Sabine Pass LNG, LP [Member] | Cooperative Endeavor Agreements [Member] | Cheniere Marketing, LLC [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
Deferred Revenue Related Party Current	17,200,000	'		17,200,000	'		14,700,000
Cheniere Energy Partners, LP [Member] | Service Agreements [Member] | Cheniere LNG Terminals, Inc. [Member]	'	'		'	'		'
Related Party Transaction [Line Items]	'	'		'	'		'
General and Administrative Expense Related Parties	$2,800,000	'		'	'		'
[1]	Retrospectively adjusted as discussed in Note 2.

Supplmental_Cash_Flow_Informat

Supplmental Cash Flow Information and Disclosures of Non-Cash Transactions (Details) (USD $)	9 Months Ended			3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012		Sep. 30, 2012	Sep. 30, 2013
				Cheniere Energy Partners, LP [Member]	Cheniere Energy Partners, LP [Member]
Supplemental Cash Flow Elements [Abstract]	'	'		'	'
Proceeds from sale Of Class B Units	$0	$1,387,560	[1]	$0	$180,000
Construction-in-process funded with accounts payable and accrued liabilities (including affiliate)	88,420	52,830		'	'
Interest Paid, Net	$56,428	$77,140		'	'
[1]	Retrospectively adjusted as discussed in Note 2.

Cash_Distributions_and_Net_Inc1

Cash Distributions and Net Income (Loss) per Common Unit - Schedule of Partner Distributions Made (Details) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

Share data in Millions, except Per Share data, unless otherwise specified

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Sep. 30, 2012

Dec. 31, 2012

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

28-May-13

Sep. 30, 2012

31-May-12

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Common Units

Common Units

Common Units

Common Units

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Subordinated Units

Subordinated Units

Subordinated Units

General Partner [Member]

General Partner [Member]

General Partner [Member]

Distribution Made to Member or Limited Partner [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of days after quarter end distribution is paid

'

'

'

'

'

$45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Date paid

15-Aug-13

15-May-13

14-Feb-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit

'

'

'

'

'

'

$0.43

$0.43

$0.43

$0.43

'

'

'

'

'

'

'

$0

$0

$0

'

'

'

Total distribution

'

'

'

'

'

'

24,259,000

24,259,000

16,783,000

'

'

'

'

0

0

0

'

0

0

0

495,000

495,000

342,000

Partner units issued and sold

'

'

'

'

'

'

'

'

'

'

12

'

133.3

'

'

'

'

'

'

'

'

'

'

Partner units issued and sold, unit price ($US$ per unit)

'

'

'

'

'

'

'

'

'

'

$15

$15

'

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of partnership units

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000,000

'

'

'

'

'

'

'

'

'

'

Discount upon issuance of Class B units representating beneficial conversion feature

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,130,000,000

'

'

'

'

'

'

Amortization of Beneficial Conversion Feature of Class B Units

'

'

'

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash_Distributions_and_Net_Inc2

Cash Distributions and Net Income (Loss) per Common Unit (Details) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

12 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

28-May-13

Sep. 30, 2012

31-May-12

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Common Units

Common Units

Common Units

Common Units

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Subordinated Units

Subordinated Units

Subordinated Units

Subordinated Units

General Partner [Member]

General Partner [Member]

General Partner [Member]

General Partner [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Common Units

Common Units

Common Units

Common Units

Common Units

Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]

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Net loss

($98,109,000)

($51,370,000)

[1]

($196,851,000)

($106,818,000)

[1]

'

'

'

($48,741,000)

'

'

'

$0

'

'

'

($123,855,000)

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'

'

($6,105,000)

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'

'

'

'

'

'

'

Partners' Capital Account, Units, Sold in Private Placement

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12,000,000

'

133,300,000

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'

'

'

'

Partners Capital Account, Units, Sold In Public Offering, Unit Price

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$15

$15

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'

'

'

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Declared distributions

24,754,000

17,125,000

74,261,000

44,376,000

'

24,259,000

16,783,000

72,776,000

43,488,000

0

0

0

0

0

0

0

0

495,000

342,000

1,485,000

888,000

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'

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Assumed allocation of undistributed net loss

-122,863,000

-68,495,000

-271,112,000

-151,194,000

'

-35,780,000

-12,467,000

-73,521,000

-28,278,000

0

0

0

0

-84,865,000

-42,744,000

-174,382,000

-96,948,000

-2,462,000

-4,336,000

-5,059,000

-5,765,000

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Assumed allocation of net income (loss)

'

'

'

'

'

-11,521,000

1,345,000

-745,000

11,347,000

0

14,888,000

0

19,625,000

-84,865,000

-54,661,000

-174,382,000

-112,710,000

-1,967,000

-3,994,000

-3,574,000

-4,877,000

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'

'

'

'

'

'

Net gain (loss) loss attributable to the Creole Trail Pipeline Business

244,000

-8,948,000

[1]

-18,150,000

-20,203,000

[1]

-20,203,000

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Weighted average units outstanding (shares)

57,079,000

[1]

'

53,277,000

[1]

'

'

57,079,000

31,997,000

[1]

53,277,000

31,449,000

[1]

0

54,710,000

0

19,181,000

'

135,384,000

135,384,000

135,384,000

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Net income (loss) per common unit (US$ per share)

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'

'

($0.20)

$0.04

[1]

($0.01)

$0.36

[1]

$0

$0.27

$0

$1.02

($0.63)

($0.40)

($1.29)

($0.83)

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Amortization of Beneficial Conversion Feature of Class B Units

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$0

'

$0

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'

($2,971,000)

'

($3,863,000)

'

$14,888,000

'

$19,625,000

'

($11,917,000)

'

($15,762,000)

'

'

'

$0

'

'

'

($538,538,000)

($32,023,000)

($241,000)

($2,000)

$0

[1]

Retrospectively adjusted as discussed in Note 2.

Cash_Distributions_and_Net_Inc3

Cash Distributions and Net Income (Loss) per Common Unit Schedule of Anticipated Beneficial Conversion Feature impact to Capital Accounts (Details) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

Sep. 30, 2012

Sep. 30, 2012

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Common Units

Common Units

Common Units

Common Units

Common Units

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Class B Unit [Member]

Subordinated Units

Subordinated Units

Subordinated Units

Subordinated Units

Subordinated Units

Cheniere Energy, Inc. [Member]

Blackstone CQP Holdco LP [Member]

Effective Yield Method [Member]

Effective Yield Method [Member]

Amortization of Beneficial Conversion Feature of Class B Units

$0

$0

($538,538,000)

($32,023,000)

($241,000)

($2,000)

$0

$1,815,883,000

$107,979,000

$813,000

$6,000

$0

($1,277,345,000)

($75,955,000)

($572,000)

($4,000)

$0

$9.43

$9.58