Cheniere Energy Partners (CQP) 10-Q 1 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	Apr. 17, 2014	Apr. 17, 2014	Apr. 17, 2014
		Common Units [Member]	Class B Units [Member]	Subordinated Units [Member]
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	'Large Accelerated Filer	'	'	'
Document Type	'10-Q	'	'	'
Document Period End Date	31-Mar-14	'	'	'
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q1	'	'	'
Amendment Flag	'false	'	'	'
Capital Unit [Line Items]	'	'	'	'
Entity Common Stock, Shares Outstanding	0	57,078,848	145,333,334	135,383,831
Entity Well-known Seasoned Issuer	'Yes	'	'	'
Entity Voluntary Filers	'No	'	'	'
Entity Current Reporting Status	'Yes	'	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$325,342	$351,032
Restricted cash and cash equivalents	176,518	227,652
Advances to affiliate	12,857	14,737
LNG inventory	4,072	10,430
Otherbaffiliate	3,285	3,280
Prepaid expenses and other	8,017	5,997
Total current assets	530,091	613,128
Non-current restricted cash and cash equivalents	323,728	1,025,056
Property, plant and equipment, net	7,028,192	6,383,939
Debt issuance costs, net	302,439	313,944
Non-current derivative assets	71,170	98,123
Advances under long-term contracts	20,364	6,561
Other	97,125	76,032
Total assets	8,373,109	8,516,783
Current liabilities	'	'
Accounts payable	4,836	10,146
Accrued liabilities	122,996	170,052
Due to affiliates	26,527	45,547
Deferred revenue	26,722	26,593
Other	19,561	13,549
Otherbaffiliate	20	0
Total current liabilities	200,662	265,887
Long-term debt, net	6,578,350	6,576,273
Deferred revenue	16,500	17,500
Other non-current liabilities	192	193
Other non-current liabilitiesbaffiliate	32,148	17,186
Commitments and contingencies	'	'
Partners' equity	'	'
Common unitholders' interest (57.1 million units issued and outstanding at March 31, 2014 and December 31, 2013)	667,246	711,771
Class B unitholders' interest (145.3 million units issued and outstanding at March 31, 2014 and December 31, 2013)	-38,216	-38,216
Subordinated unitholders' interest (135.4 million units issued and outstanding at March 31, 2014 and December 31, 2013)	883,002	931,074
General partner's interest (2% interest with 6.9 million units issued and outstanding at March 31, 2014 and December 31, 2013, respectively)	33,225	35,115
Total partners' equity	1,545,257	1,639,744
Total liabilities and partners' equity	$8,373,109	$8,516,783

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet Parentheticals	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
General Partner Ownership Interest Percentage	2.00%	2.00%
General Partners' Capital Account, Units Issued	6,894	6,894
General partner units outstanding	6,894	6,894
Common Units [Member]	'	'
Limited Partners' Capital Account, Units Issued	57,078	57,078
Partnership unitholders units outstanding	57,078	57,078
Class B Units [Member]	'	'
Limited Partners' Capital Account, Units Issued	145,333	145,333
Partnership unitholders units outstanding	145,333	14,533
Subordinated Units [Member]	'	'
Limited Partners' Capital Account, Units Issued	135,384	135,384
Partnership unitholders units outstanding	135,384	135,384

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Revenues	'	'
Revenues	$66,449	$65,563	[1]
Revenuesbaffiliate	772	545	[1]
Total revenues	67,221	66,108	[1]
Expenses	'	'
Operating and maintenance expense	9,219	8,286	[1]
Operating and maintenance expensebaffiliate	4,431	6,923	[1]
Depreciation expense	14,318	14,304	[1]
Development expense	3,496	3,484	[1]
Development expensebaffiliate	152	451	[1]
General and administrative expense	3,366	3,774	[1]
General and administrative expensebaffiliate	27,153	23,216	[1]
Total expenses	62,135	60,438	[1]
Income from operations	5,086	5,670	[1]
Other income (expense)	'	'
Interest expense, net	-40,270	-40,262	[1]
Derivative loss, net	-34,681	-17,468	[1]
Other income	132	327	[1]
Total other expense	-74,819	-57,403	[1]
Net loss	-69,733	-51,733	[1]
Net loss attributable to the Creole Trail Pipeline Business	0	-9,246	[1]
Net loss attributable to partners	($69,733)	($42,487)	[1]
Basic and diluted net income (loss) per common unit	($0.06)	$0.10	[1]
Weighted average number of common units outstanding used for basic and diluted net income (loss) per common unit calculation	57,079	45,547	[1]
[1]	Retrospectively adjusted as discussed in Note 1.

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Loss (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Statement of Comprehensive Income [Abstract]	'	'
Net loss	($69,733)	($51,733)	[1]
Other comprehensive income (loss)	'	'
Loss on settlements retained in other comprehensive income	0	-30	[1]
Change in fair value of interest rate cash flow hedges	0	21,297	[1]
Total other comprehensive income	0	21,267	[1]
Comprehensive loss	($69,733)	($30,466)	[1]
[1]	Retrospectively adjusted as discussed in Note 1.

Consolidated_Statements_of_Par

Consolidated Statements of Partners' and Owners' Equity (USD $)	Total	Common Units [Member]	Class B Unit [Member]	Subordinated Units [Member]	General Partner [Member]
In Thousands, unless otherwise specified
Partners' equity, beginning of period at Dec. 31, 2013	$1,639,744	$711,771	($38,216)	$931,074	$35,115
General partner units outstanding, beginning of period at Dec. 31, 2013	6,894	'	'	'	6,894
Units outstanding, beginning of period at Dec. 31, 2013	'	57,078	145,333	135,384	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'
Net loss	-69,733	-20,266	0	-48,072	-1,395
Distributions	-24,754	-24,259	0	0	-495
Partners' equity, end of period at Mar. 31, 2014	$1,545,257	$667,246	($38,216)	$883,002	$33,225
General partner units outstanding, end of period at Mar. 31, 2014	6,894	'	'	'	6,894
Units outstanding, end of period at Mar. 31, 2014	'	57,078	145,333	135,384	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows from operating activities	'	'
Net loss	($69,733)	($51,733)	[1]
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:	'	'
Depreciation	14,318	14,304	[1]
Use of restricted cash and cash equivalents for certain operating activities	-22,873	-27,542	[1]
Amortization of debt issuance costs and discount	2,217	2,210	[1]
Non-cash derivative loss, net	32,995	18,118	[1]
Other	2	3,064	[1]
Changes in operating assets and liabilities:	'	'
Accounts receivablebaffiliate	593	1,044	[1]
Accounts payable and accrued liabilities	39,263	41,854	[1]
Due to affiliates	3,669	6,881	[1]
Deferred revenue	-871	-2,210	[1]
Advances to affiliate	1,880	-4,552	[1]
LNG inventory	2,902	0	[1]
Other	-4,251	-448	[1]
Otherbaffiliate	-567	1,277	[1]
Net cash provided by (used in) operating activities	-456	2,267	[1]
Cash flows from investing activities	'	'
Property, plant and equipment, net	-751,808	-465,044	[1]
Use of restricted cash and cash equivalents for the acquisition of property, plant and equipment	761,378	463,476	[1]
Advances under long-term contracts	-10,050	-964	[1]
Net cash used in investing activities	-480	-2,532	[1]
Cash flows from financing activities	'	'
Proceeds from issuances of long-term debt	0	1,500,000	[1]
Proceeds from sale of partnership common and general partner units, net	0	372,449	[1]
Contributions to Creole Trail Pipeline Business from Cheniere, net	0	7,936	[1]
Use of (investment in) restricted cash and cash equivalents	13,957	-1,790,446	[1]
Debt issuance and deferred financing costs	-13,957	-34,986	[1]
Distributions to owners	-24,754	-17,125	[1]
Other	0	-3	[1]
Net cash provided by (used in) financing activities	-24,754	37,825	[1]
Net increase (decrease) in cash and cash equivalents	-25,690	37,560	[1]
Cash and cash equivalentsbbeginning of period	351,032	419,292	[1]
Cash and cash equivalentsbend of period	$325,342	$456,852	[1]
[1]	Retrospectively adjusted as discussed in Note 1.

Basis_of_Presentation_Notes

Basis of Presentation (Notes)	3 Months Ended
	Mar. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [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 accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. As used in these Notes to Consolidated Financial Statements, the terms "Cheniere Energy Partners", "we", "us" and "our" refer to Cheniere Energy Partners, L.P. and its wholly owned subsidiaries, unless otherwise stated or indicated by context.
	Results of operations for the three months ended March 31, 2014 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2014.
	Subsequent to the acquisition of Cheniere Energy, Inc.'s ("Cheniere's") ownership in Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, "the Creole Trail Pipeline Business") in May 2013, 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.
	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 the Creole Trail Pipeline Business in our Consolidated Statements of Operations. 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 retroactively 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.
	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.
	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, 2013.

Unitholders_Equity_Notes

Unitholders' Equity (Notes)	3 Months Ended
	Mar. 31, 2014
Description of Equity Interests [Abstract]	'
Description of Equity Interests	'
	UNITHOLDERS' EQUITY
	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. 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 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. 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.  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.
	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%.
	During 2012, Blackstone CQP Holdco LP ("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 were used to fund a portion of the costs of developing, constructing and placing into service the first two Trains of the natural gas liquefaction facilities at the Sabine Pass LNG terminal adjacent to the existing regasification facilities (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 our acquisition of the Creole Trail Pipeline Business described in Note 1—"Basis of Presentation".  In 2013, Cheniere formed Cheniere Energy Partners LP Holdings, LLC ("Cheniere Holdings") to hold its limited partner interests in us. The Class B units are subject to conversion, mandatorily or at the option of the Class B unitholders under specified circumstances, into a number of common units based on the then-applicable conversion value of the Class B units. The Class B units are not entitled to cash distributions except in the event of a liquidation (or merger, combination or sale of substantially all of our assets). 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 additional upward adjustment for certain equity and debt financings. The accreted conversion ratio of the Class B units owned by Cheniere Holdings and Blackstone was 1.27 and 1.25, respectively, as of March 31, 2014. We expect the Class B units to mandatorily convert into common units within 90 days of the substantial completion date of Train 3 of the Liquefaction Project, which we currently expect 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.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents (Notes)	3 Months Ended
	Mar. 31, 2014
Cash and Cash Equivalents [Abstract]	'
Restricted Cash and Cash Equivalents	'
	RESTRICTED CASH AND CASH EQUIVALENTS
	Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. Restricted cash and cash equivalents include the following:
	Sabine Pass LNG Senior Notes Debt Service Reserve
	Sabine Pass LNG, L.P. ("Sabine Pass LNG"), our wholly owned subsidiary, has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of 7.50% Senior Secured Notes due 2016 (the "2016 Notes") and $420.0 million of 6.50% 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 the condition 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 March 31, 2014 and December 31, 2013, we classified $53.0 million and $15.0 million, respectively, as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of both March 31, 2014 and December 31, 2013, 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.
	Sabine Pass Liquefaction Reserve
	In July 2012, Sabine Pass Liquefaction, LLC ("Sabine Pass Liquefaction"), our wholly owned subsidiary, entered into a construction/term loan facility in an amount up to $3.6 billion (the "2012 Liquefaction Credit Facility"). During 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion, before premium, of 5.625% Senior Secured Notes due 2021 (the "2021 Sabine Pass Liquefaction Senior Notes"), $1.0 billion of 6.25% Senior Secured Notes due 2022 (the "2022 Sabine Pass Liquefaction Senior Notes") and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the "2023 Sabine Pass Liquefaction Senior Notes" and collectively with the 2021 Sabine Pass Liquefaction Senior Notes and the 2022 Sabine Pass Liquefaction Senior Notes, the "Sabine Pass Liquefaction Senior Notes"). Also during 2013, Sabine Pass Liquefaction entered into four credit facilities aggregating $5.9 billion (collectively, the "2013 Liquefaction Credit Facilities"), which amended and restated the 2012 Liquefaction Credit Facility. See Note 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 reserve 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 March 31, 2014 and December 31, 2013, we classified $96.9 million and $192.1 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 $197.5 million and $867.6 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 March 31, 2014 and December 31, 2013, we classified $26.6 million and $20.5 million, respectively, as current restricted cash and cash equivalents held by CTPL and $50.1 million and $81.4 million, respectively, as non-current restricted cash and cash equivalents held by CTPL because such funds may only be used for modifications of the 94-mile Creole Trail Pipeline, which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines, 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)	3 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		March 31,			December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	2,232,495		$	2,225,412
	LNG terminal construction-in-process	5,099,744			4,448,541
	LNG site and related costs, net	147			149
	Accumulated depreciation	(305,574		)	(291,265		)
	Total LNG terminal costs, net	7,026,812			6,382,837
	Fixed assets
	Computer and office equipment	613			612
	Vehicles	1,306			907
	Machinery and equipment	1,490			1,490
	Other	1,014			963
	Accumulated depreciation	(3,043		)	(2,870		)
	Total fixed assets, net	1,380			1,102
	Property, plant and equipment, net	$	7,028,192		$	6,383,939
	Depreciation expense related to the Sabine Pass LNG terminal totaled $14.3 million for each of the three months ended March 31, 2014 and 2013.
	In June 2012, we began capitalizing costs associated with Trains 1 and 2 of the Liquefaction Project, and in May 2013, we began capitalizing costs associated with Trains 3 and 4 of the Liquefaction Project. For the three months ended March 31, 2014 and 2013, we capitalized $78.8 million and $35.3 million, respectively, of interest expense related to the construction of the first four Trains of the Liquefaction Project.

Financial_Instruments_Notes

Financial Instruments (Notes)	3 Months Ended
	Mar. 31, 2014
Financial Instruments [Abstract]	'
Fair Value Disclosures [Text Block]	'
	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"). We have also entered into 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 March 31, 2014 and December 31, 2013, which are classified as prepaid expenses and other, non-current derivative assets and other current liabilities in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		31-Mar-14																31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total				Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)		Total
		(Level 1)																(Level 1)
	LNG Inventory Derivatives asset (liability)	$	—			$	35			$	—			$	35			$	—			$	(161	)		$	—	$	(161	)
	Fuel Derivatives asset	—				19				—				19				—				27				—		27
	Interest Rate Derivatives asset	—				51,626				—				51,626				—				84,639				—		84,639
	The estimated fair values of our LNG Inventory Derivatives and Fuel Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. 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 $0.5 million and $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 March 31, 2014 and December 31, 2013, respectively.
	During the second quarter of 2013, Sabine Pass LNG began to enter into forward contracts under an International Swaps and Derivatives Association master agreement with Cheniere Marketing, LLC ("Cheniere Marketing"), a wholly owned subsidiary of Cheniere, to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate 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 March 31, 2014.
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			March 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset (liability)	Prepaid expenses and other			$	35			$	(161	)
	Fuel Derivatives asset	Prepaid expenses and other			19				27
	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 months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	LNG Inventory Derivatives loss	$	(29	)		$	(550	)
	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 loss, net on our Consolidated Statements of Operations during the three months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	LNG Inventory Derivatives loss	$	(435	)		$	—
	Fuel Derivatives gain (1)	242				515
	(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 our Consolidated Statements of Operations.
	During the first quarter of 2013, Sabine Pass Liquefaction 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 7—"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 were recorded as other comprehensive income (loss) within our Consolidated Balance Sheets, and changes in fair value subsequent to their de-designation date were recorded as derivative gain (loss) within our Consolidated Statements of Operations.
	In June 2013, Sabine Pass Liquefaction 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 Sabine Pass Liquefaction's intention to continue to issue fixed rate debt to refinance the 2013 Liquefaction Credit Facilities. As a result, the amount remaining in accumulated other comprehensive income ("AOCI") pertaining to the previously designated Interest Rate Derivatives was reclassified out of AOCI and into income. We have presented the 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 March 31, 2014, 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		June 5, 2013		May 28, 2020		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		March 31, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	71,170			$	98,123
	Interest Rate Derivatives - Not Designated		Other current liabilities		(19,544		)		(13,484		)
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income ("OCI") and AOCI during the three months ended March 31, 2014 and 2013:
		Gain (Loss) in Other Comprehensive Income								Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)								Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
		2014				2013				2014				2013				2014				2013
	Interest Rate Derivatives - Designated	$	—			$	21,297			$	—			$	—			$	—			$	—
	Interest Rate Derivatives - Settlements	—				(30		)		—				—				—				—
	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives—Not Designated recorded in derivative loss, net on our Consolidated Statements of Operations during the three months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	Interest Rate Derivatives - Not Designated	$	(34,479	)		$	(17,983	)
	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 Sheets				Net Amounts Presented in the Consolidated Balance Sheets				Gross Amounts Not Offset in the Consolidated Balance Sheets
	Offsetting Derivative Assets (Liabilities)															Derivative Instrument				Cash Collateral Received (Paid)				Net Amount
	As of March 31, 2014:
	Fuel Derivatives		$	19				$	—			$	19			$	—			$	—			$	19
	LNG Inventory Derivatives		35					7				28				—				—				28
Interest Rate Derivatives - Not Designated		71,170					—				71,170				—				—				71,170
Interest Rate Derivatives - Not Designated		(19,544		)			—				(19,544		)		—				—				(19,544		)
As of December 31, 2013:					—
Fuel Derivatives		27					—				27				—				—				27
LNG Inventory Derivatives		(161		)			(161		)		—				—				—				—
Interest Rate Derivatives - Not Designated		98,123					—				98,123				—				—				98,123
Interest Rate Derivatives - Not Designated		(13,484		)			—				(13,484		)		—				—				(13,484		)
Other Financial Instruments
The estimated fair value of our other financial instruments, including those financial instruments for which the fair value option was not elected are set forth in the table below.  The carrying amounts reported on our 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.
The following table (in thousands) shows the carrying amount and estimated fair value of our other financial instruments:
		March 31, 2014								December 31, 2013
		Carrying				Estimated				Carrying				Estimated
		Amount				Fair Value				Amount				Fair Value
2016 Notes, net of discount (1)		$	1,652,981			$	1,824,478			$	1,651,807			$	1,868,607
2020 Notes (1)		420,000				441,000				420,000				432,600
2021 Sabine Pass Liquefaction Senior Notes (1)		2,011,222				2,079,101				2,011,562				1,961,273
2022 Sabine Pass Liquefaction Senior Notes (1)		1,000,000				1,042,500				1,000,000				982,500
2023 Sabine Pass Liquefaction Senior Notes (1)		1,000,000				997,500				1,000,000				935,000
2013 Liquefaction Credit Facilities (2)		100,000				100,000				100,000				100,000
CTPL Credit Facility (3)		394,147				400,000				392,904				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 March 31, 2014 and December 31, 2013, as applicable.
-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at any time 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 any time without penalty.

Accrued_Liabilities_Notes

Accrued Liabilities (Notes)	3 Months Ended
	Mar. 31, 2014
Accrued Liabilities [Abstract]	'
Accrued Liabilities	'
	ACCRUED LIABILITIES
	As of March 31, 2014 and December 31, 2013, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		March 31,		December 31,
		2014		2013
	Interest and related debt fees	$	101,637	$	80,151
	Liquefaction Project costs	17,642		83,127
	LNG terminal costs	1,612		1,612
	Other	2,105		5,162
	Total accrued liabilities	122,996		170,052
	Accrued liabilities—affiliate	25,287		44,384
	Total accrued liabilities (including affiliate)	$	148,283	$	214,436

LongTerm_Debt_Notes

Long-Term Debt (Notes)	3 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
Debt Disclosure	'
	LONG-TERM DEBT
	As of March 31, 2014 and December 31, 2013, our long-term debt consisted of the following (in thousands):
			March 31,			December 31,
			2014			2013
	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			2,000,000
	2022 Sabine Pass Liquefaction Senior Notes		1,000,000			1,000,000
	2023 Sabine Pass Liquefaction Senior Notes		1,000,000			1,000,000
	2013 Liquefaction Credit Facilities		100,000			100,000
	CTPL Credit Facility		400,000			400,000
	Total long-term debt		6,585,500			6,585,500
	Long-term debt premium (discount)
	2016 Notes		(12,519		)	(13,693		)
	2021 Sabine Pass Liquefaction Senior Notes		11,222			11,562
	CTPL Credit Facility		(5,853		)	(7,096		)
	Total long-term debt, net of discount		$	6,578,350		$	6,576,273
	Sabine Pass LNG Senior Notes
	As of March 31, 2014 and December 31, 2013, 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 Sabine Pass LNG Senior Notes is payable semi-annually in arrears. 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 all or part of the 2016 Notes at any time, and from time to time, at a redemption price equal to 100% of the principal plus any accrued and unpaid interest plus the greater of:
	•	1.0% of the principal amount of the 2016 Notes; or
	•	the excess of: a) the present value at such redemption date of (i) the redemption price of the 2016 Notes plus (ii) all required interest payments due on the 2016 Notes (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 50 basis points; over b) the principal amount of the 2016 Notes, if greater.
	Sabine Pass LNG may redeem all or part of the 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, including: (i) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (ii) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. During the three months ended March 31, 2014 and 2013, Sabine Pass LNG made distributions of $63.4 million and $76.7 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 2021 Sabine Pass Liquefaction Senior Notes and 2023 Sabine Pass Liquefaction Senior Notes bear interest at a fixed rate of 5.625%. In November 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $1.0 billion of the 2022 Sabine Pass Liquefaction Senior Notes. Borrowings under the 2022 Sabine Pass Liquefaction Senior Notes bear interest at a fixed rate of 6.25%. Interest on the Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears.
	The terms of the 2021 Sabine Pass Liquefaction Senior Notes, the 2022 Sabine Pass Liquefaction Senior Notes and the 2023 Sabine Pass Liquefaction Senior Notes are governed by a common indenture (the "Sabine Pass Liquefaction Indenture"). The Sabine Pass Liquefaction 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 Trains 1 and 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.
	At any time prior to November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes; December 15, 2021, with respect to the 2022 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 part of the Sabine Pass Liquefaction Senior Notes at a redemption price equal to the "make-whole" price set forth in the Sabine Pass Liquefaction Indenture, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass Liquefaction may also at any time on or after November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes; December 15, 2021, with respect to the 2022 Sabine Pass Liquefaction Senior Notes; or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, redeem all or part of the Sabine Pass Liquefaction Senior Notes 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 issuance of the 2022 Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction also entered into a registration rights agreement (the "2022 Liquefaction Registration Rights Agreement"). Under the 2022 Liquefaction Registration Rights Agreement, Sabine Pass Liquefaction has agreed to use commercially reasonable efforts to file with the Securities and Exchange Commission ("SEC") and cause to become effective a registration statement relating to an offer to exchange the 2022 Sabine Pass Liquefaction Senior Notes for a like aggregate principal amount of SEC-registered notes with terms identical in all material respects to the 2022 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 November 25, 2013.  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 this obligation, Sabine Pass Liquefaction may be required to pay additional interest to holders of the 2022 Sabine Pass Liquefaction Senior Notes under certain circumstances.
	2013 Liquefaction Credit Facilities
	In May 2013, Sabine Pass Liquefaction entered into the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four Trains of the Liquefaction Project. The 2013 Liquefaction Credit Facilities will mature on the earlier of May 28, 2020 or the second anniversary of the completion date of the first four Trains of the Liquefaction Project, as defined in the 2013 Liquefaction Credit Facilities. Borrowings under the 2013 Liquefaction Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent.
	Sabine Pass Liquefaction had $4.9 billion of available commitments under the 2013 Liquefaction Credit Facilities as of both March 31, 2014 and December 31, 2013, as a result of Sabine Pass Liquefaction's initial $100.0 million borrowing and the termination of approximately $885 million of commitments in connection with the issuance of the 2022 Sabine Pass Liquefaction Senior Notes in November 2013 as described below.
	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 range from 2.3% to 3.0% prior to the completion of Train 4 and from 2.3% to 3.25%, after such completion, depending on the applicable 2013 Liquefaction Credit Facility. Interest on LIBOR loans is due and payable at the end of each LIBOR period. The 2013 Liquefaction Credit Facilities required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144 million and provide for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment due quarterly in arrears. Annual administrative fees must also be paid to the agent and the trustee. The principal of the loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing with the earlier of the last day of the first full calendar quarter after the Train 4 completion date, as defined in the 2013 Liquefaction Credit Facilities, or September 30, 2018. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2013 Liquefaction Credit Facilities.
	Under the terms and conditions of the 2013 Liquefaction Credit Facilities, all cash held by 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".
	In November 2013, Sabine Pass Liquefaction issued the 2022 Sabine Pass Liquefaction Senior Notes, and a portion of the available commitments pursuant to the 2013 Liquefaction Credit Facilities was terminated. Net proceeds from the offering of approximately $978 million are being used to pay a portion of the capital costs in connection with the construction of the first four Trains of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2013 Liquefaction Credit Facilities. The 2022 Sabine Pass Liquefaction Notes are pari passu in right of payment with all existing and future senior debt of Sabine Pass Liquefaction. As a result of Sabine Pass Liquefaction's issuance of the 2022 Sabine Pass Liquefaction Senior Notes in November 2013, Sabine Pass Liquefaction has terminated approximately $885 million of commitments under the 2013 Liquefaction Credit Facilities. This termination resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Liquefaction Credit Facilities of $43.3 million in November 2013.
	2012 Liquefaction Credit Facility
	In July 2012, Sabine Pass Liquefaction entered into the 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 and 2 of the Liquefaction Project. Borrowings under the 2012 Liquefaction Credit Facility were based on LIBOR plus 3.50% during construction and LIBOR plus 3.75% during operations. Sabine Pass Liquefaction was also required to pay commitment fees on the undrawn amount. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.
	Under the terms of the 2012 Liquefaction Credit Facility, 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".
	CTPL Credit Facility
	In May 2013, CTPL entered into the CTPL Credit Facility, which is being 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 March 31, 2014, 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.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	As of March 31, 2014 and December 31, 2013, we had $12.9 million and $14.7 million of advances to affiliates, respectively. In addition, we have entered into the following related party transactions:
	LNG Terminal Capacity Agreements
	Terminal Use Agreement ("TUA")
	Sabine Pass Liquefaction obtained approximately 2.0 Bcf/d of regasification capacity under a TUA with Sabine Pass LNG as a result of an assignment in July 2012 by 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.
	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 three months ended March 31, 2014 and 2013, we recorded credits of $0.5 million and $0.3 million, respectively, against operating and maintenance expense related to this obligation.
	Cheniere Investments, Sabine Pass Liquefaction and Sabine Pass LNG entered into the 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 the 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.
	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/yr of LNG. 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, which is included in other—affiliate on our Consolidated Balance Sheets. This amount 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 March 31, 2014, we had 10,500 MMBtu of LNG inventory—affiliate recorded at $34 thousand on our Consolidated Balance Sheets, and as of December 31, 2013, we had 41,000 MMBtu of LNG inventory—affiliate recorded at $130 thousand in other—affiliate on our Consolidated Balance Sheets.
	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 March 31, 2014 and December 31, 2013 was $2.0 thousand and $0.2 million, respectively, and was classified as other current assets and other current liabilities, respectively, 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 losses of $29.0 thousand and $0.6 million related to LNG inventory—affiliate derivatives in the three months ended March 31, 2014 and 2013, respectively.
	Service Agreements
	During the three months ended March 31, 2014 and 2013, we recorded general and administrative expense—affiliate of $27.2 million and $23.2 million, respectively, and operating and maintenance expense—affiliate of $4.4 million and $6.9 million, respectively, under the service agreements described below.
	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 Cheniere Investments pursuant to which Sabine Pass LNG receives 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 Sabine Pass LNG O&M Agreement, and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between 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. Cheniere Investments provides the services required under the Sabine Pass LNG O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	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
	Sabine Pass Liquefaction has entered into an operation and maintenance agreement (the "Liquefaction O&M Agreement") with Cheniere Investments pursuant to which Sabine Pass Liquefaction receives 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. Cheniere Investments provides the services required under the Liquefaction O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	Sabine Pass Liquefaction MSA
	Sabine Pass Liquefaction has entered into a management services agreement (the "Liquefaction MSA") with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the liquefaction facilities, excluding those matters provided for under the Liquefaction O&M Agreement. The services include, among other services, exercising the day-to-day management of 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, entering into financial derivatives on our behalf, and providing contract administration services for all contracts associated with the liquefaction facilities. Sabine Pass Liquefaction pays 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 will pay a fixed monthly fee of $541,667 for services with respect to such Train.
	CTPL O&M Agreement
	CTPL has entered into an amended long-term operation and maintenance agreement (the "CTPL O&M Agreement") with Cheniere Investments pursuant to which CTPL receives 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. In November 2013, the CTPL O&M Agreement was assigned by Cheniere Energy Partners GP, LLC to Cheniere Investments. Cheniere Investments provides the services required under the CTPL O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	CTPL MSA
	CTPL has entered into a management services agreement (the "CTPL MSA") with Cheniere Terminals pursuant to which Cheniere Terminals manages the modification and operation of the Creole Trail Pipeline, excluding those matters provided for under the CTPL O&M Agreement. The services 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 ("CEAs")
	In July 2007, Sabine Pass LNG executed 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 commitment of up to $25.0 million and Sabine Pass LNG 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 advance 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 entered into an agreement 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 during construction of the Liquefaction Project the capacity rights granted under the TURA. Cheniere Marketing will continue to fund the CEAs during the term of the amended and restated VCRA and, in exchange, Cheniere Marketing will receive the benefit of any future credits.
	On a consolidated basis, these advance tax payments were recorded to other non-current assets, and payments from Cheniere Marketing that Sabine Pass LNG utilized to make the ad valorem tax payments were recorded as a long-term obligation. As of March 31, 2014 and December 31, 2013, we had $19.6 million and $17.2 million, respectively, of other non-current assets resulting from Sabine Pass LNG's ad valorem tax payments and non-current liabilities—affiliate resulting from these payments received from Cheniere Marketing.
	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 natural gas or LNG to the Sabine Pass LNG terminal. As a result, Sabine Pass LNG records the purchases of natural gas and LNG from Cheniere Marketing to be utilized as fuel to operate the Sabine Pass LNG terminal as operating and maintenance expense. Sabine Pass LNG recorded $0.5 million and $0.9 million of natural gas purchased from Cheniere Marketing under these agreements as operating and maintenance expense in the three months ended March 31, 2014 and 2013, respectively. Sabine Pass LNG recorded revenues—affiliate of zero and $0.9 million for natural gas sold to Cheniere Marketing under these agreements in the three months ended March 31, 2014 and 2013, 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 March 31, 2014 and 2013.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information and Disclosures of Non-Cash Transactions (Notes)	3 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Elements [Abstract]	'
Cash Flow, Supplemental Disclosures	'
	SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Three Months Ended March 31,
		2014		2013
	Cash paid during the year for interest, net of amounts capitalized	$	16,567	$	—
	LNG terminal costs funded with accounts payable and accrued liabilities (including affiliate)	67,768		176,488

Net_Income_Loss_per_Common_Uni

Net Income (Loss) per Common Unit (Notes)	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Cash Distributions and Net Income (Loss) per Common Unit	'
	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. Distributions paid by us are presented on the Consolidated Statements of Partners' and Owners' Equity. On April 21, 2014, we declared a $0.425 distribution per common unit and the related distribution to our general partner to be paid to owners of record on May 1, 2014 for the period from January 1, 2014 to March 31, 2014.
	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. Historical income (losses) attributable to a company that was purchased from an entity under common control are allocated to the predecessor owner in accordance with the terms 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.
	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 Statements of Partners' and Owners' Equity.  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 Holdings' and Blackstone's Class B units, respectively, although actual conversion may occur prior to or after these assumed dates. We are amortizing using the effective yield method with a weighted average effective yield of 888.7% per year and 966.1% per year for Cheniere Holdings' and Blackstone's Class B units, respectively. The impact of the beneficial conversion feature is also included in earnings per unit for the three months ended March 31, 2014 and 2013.
	The following is a schedule by years, based on the capital structure as of March 31, 2014, 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
	2014	(2	)		6		(4	)
	2015	(232	)		781		(549	)
	2016	(29,564	)		99,685		(70,121	)
	2017	(594,390	)		2,004,209		(1,409,819	)
	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, the subordinated units, the General Partner and Creole Trail Pipeline Business for purposes of computing net income (loss) per unit (in thousands, except per unit data). The following table also provides net income (loss) per unit, as adjusted, assuming the common units, subordinated units and General Partner had participated in the pre-acquisition date net losses of the Creole Trail Pipeline Business.
	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 March 31, 2014
	Net loss		$	(69,733	)
	Declared distributions		24,754			24,259			—		—			495
	Assumed allocation of undistributed net loss		$	(94,487	)	(27,462		)	—		(65,135		)	(1,890		)	—
	Assumed allocation of net loss					$	(3,203	)	$	—	$	(65,135	)	$	(1,395	)	$	—
	Weighted average units outstanding					57,079			145,333		135,384
	Net loss per unit					$	(0.06	)	$	—	$	(0.48	)
	Three Months Ended March 31, 2013
	Net loss		$	(51,733	)
	Declared distributions		24,754			24,259			—		—			495
	Assumed allocation of undistributed net loss		$	(76,487	)	(19,543		)	—		(46,353		)	(1,345		)	(9,246		)
	Assumed allocation of net income (loss)					$	4,716		$	—	$	(46,353	)	$	(850	)	$	(9,246	)
	Assumed allocation of net loss adjusted for the Creole Trail Pipeline Business					$	2,029		$	—	$	(52,727	)	$	(1,035	)
	Weighted average units outstanding					45,547			133,333		135,384
	Net income (loss) per unit					$	0.1		$	—	$	(0.34	)
	Net income (loss) per unit, adjusted to include pre-acquisition date net losses of the Creole Trail Pipeline Business					$	0.04		$	—	$	(0.39	)

Basis_of_Presentation_Basis_of

Basis of Presentation Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	The accompanying unaudited Consolidated Financial Statements of Cheniere Energy Partners, L.P. have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. As used in these Notes to Consolidated Financial Statements, the terms "Cheniere Energy Partners", "we", "us" and "our" refer to Cheniere Energy Partners, L.P. and its wholly owned subsidiaries, unless otherwise stated or indicated by context.
	Results of operations for the three months ended March 31, 2014 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2014.
	Subsequent to the acquisition of Cheniere Energy, Inc.'s ("Cheniere's") ownership in Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, "the Creole Trail Pipeline Business") in May 2013, 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.
	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 the Creole Trail Pipeline Business in our Consolidated Statements of Operations. 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 retroactively 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.
	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.
	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, 2013.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment [Abstract]	'
Schedule of Capitalized Costs and Fixed Assets	'
	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		March 31,			December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	2,232,495		$	2,225,412
	LNG terminal construction-in-process	5,099,744			4,448,541
	LNG site and related costs, net	147			149
	Accumulated depreciation	(305,574		)	(291,265		)
	Total LNG terminal costs, net	7,026,812			6,382,837
	Fixed assets
	Computer and office equipment	613			612
	Vehicles	1,306			907
	Machinery and equipment	1,490			1,490
	Other	1,014			963
	Accumulated depreciation	(3,043		)	(2,870		)
	Total fixed assets, net	1,380			1,102
	Property, plant and equipment, net	$	7,028,192		$	6,383,939

Financial_Instruments_Tables

Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]	'
Fair Value of Derivative Assets and Liabilities	'
	The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of March 31, 2014 and December 31, 2013, which are classified as prepaid expenses and other, non-current derivative assets and other current liabilities in our Consolidated Balance Sheets.
		Fair Value Measurements as of
		31-Mar-14																31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total				Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)		Total
		(Level 1)																(Level 1)
	LNG Inventory Derivatives asset (liability)	$	—			$	35			$	—			$	35			$	—			$	(161	)		$	—	$	(161	)
	Fuel Derivatives asset	—				19				—				19				—				27				—		27
	Interest Rate Derivatives asset	—				51,626				—				51,626				—				84,639				—		84,639
Fair Value of Derivative Instruments by Balance Sheet Location	'
	The following table (in thousands) shows the fair value and location of our LNG Inventory Derivatives and Fuel Derivatives on our Consolidated Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			March 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset (liability)	Prepaid expenses and other			$	35			$	(161	)
	Fuel Derivatives asset	Prepaid expenses and other			19				27
Schedule of Notional Amounts of Outstanding Derivative Positions	'
	At March 31, 2014, 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		June 5, 2013		May 28, 2020		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		March 31, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	71,170			$	98,123
	Interest Rate Derivatives - Not Designated		Other current liabilities		(19,544		)		(13,484		)
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	'
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income ("OCI") and AOCI during the three months ended March 31, 2014 and 2013:
		Gain (Loss) in Other Comprehensive Income								Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)								Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
		2014				2013				2014				2013				2014				2013
	Interest Rate Derivatives - Designated	$	—			$	21,297			$	—			$	—			$	—			$	—
	Interest Rate Derivatives - Settlements	—				(30		)		—				—				—				—
Derivative Gross Presentation on Consolidated Balance Sheets	'
	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 Sheets				Net Amounts Presented in the Consolidated Balance Sheets				Gross Amounts Not Offset in the Consolidated Balance Sheets
	Offsetting Derivative Assets (Liabilities)															Derivative Instrument				Cash Collateral Received (Paid)				Net Amount
	As of March 31, 2014:
	Fuel Derivatives		$	19				$	—			$	19			$	—			$	—			$	19
	LNG Inventory Derivatives		35					7				28				—				—				28
	Interest Rate Derivatives - Not Designated		71,170					—				71,170				—				—				71,170
	Interest Rate Derivatives - Not Designated		(19,544		)			—				(19,544		)		—				—				(19,544		)
	As of December 31, 2013:					—
	Fuel Derivatives		27					—				27				—				—				27
	LNG Inventory Derivatives		(161		)			(161		)		—				—				—				—
	Interest Rate Derivatives - Not Designated		98,123					—				98,123				—				—				98,123
	Interest Rate Derivatives - Not Designated		(13,484		)			—				(13,484		)		—				—				(13,484		)
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	'
			March 31, 2014								December 31, 2013
			Carrying				Estimated				Carrying				Estimated
			Amount				Fair Value				Amount				Fair Value
	2016 Notes, net of discount (1)		$	1,652,981			$	1,824,478			$	1,651,807			$	1,868,607
	2020 Notes (1)		420,000				441,000				420,000				432,600
	2021 Sabine Pass Liquefaction Senior Notes (1)		2,011,222				2,079,101				2,011,562				1,961,273
	2022 Sabine Pass Liquefaction Senior Notes (1)		1,000,000				1,042,500				1,000,000				982,500
	2023 Sabine Pass Liquefaction Senior Notes (1)		1,000,000				997,500				1,000,000				935,000
	2013 Liquefaction Credit Facilities (2)		100,000				100,000				100,000				100,000
	CTPL Credit Facility (3)		394,147				400,000				392,904				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 March 31, 2014 and December 31, 2013, as applicable.
	-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at any time 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 any time without penalty.
Sales Revenue from Energy Commodities and Services [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Derivative Instruments, Gain (Loss)	'
	The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives recorded in revenues on our Consolidated Statements of Operations during the three months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	LNG Inventory Derivatives loss	$	(29	)		$	(550	)
Derivative gain (loss), net [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Derivative Instruments, Gain (Loss)	'
	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 loss, net on our Consolidated Statements of Operations during the three months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	LNG Inventory Derivatives loss	$	(435	)		$	—
	Fuel Derivatives gain (1)	242				515
	(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 Contract [Member] | Derivative gain (loss), net [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Derivative Instruments, Gain (Loss)	'
	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives—Not Designated recorded in derivative loss, net on our Consolidated Statements of Operations during the three months ended March 31, 2014 and 2013:
		Three Months Ended March 31,
		2014				2013
	Interest Rate Derivatives - Not Designated	$	(34,479	)		$	(17,983	)

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2014
Payables and Accruals [Abstract]	'
Schedule of Accrued Liabilities	'
	As of March 31, 2014 and December 31, 2013, accrued liabilities (including amounts due to affiliates) consisted of the following (in thousands):
		March 31,		December 31,
		2014		2013
	Interest and related debt fees	$	101,637	$	80,151
	Liquefaction Project costs	17,642		83,127
	LNG terminal costs	1,612		1,612
	Other	2,105		5,162
	Total accrued liabilities	122,996		170,052
	Accrued liabilities—affiliate	25,287		44,384
	Total accrued liabilities (including affiliate)	$	148,283	$	214,436

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments	'
	As of March 31, 2014 and December 31, 2013, our long-term debt consisted of the following (in thousands):
		March 31,			December 31,
		2014			2013
	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			2,000,000
	2022 Sabine Pass Liquefaction Senior Notes	1,000,000			1,000,000
	2023 Sabine Pass Liquefaction Senior Notes	1,000,000			1,000,000
	2013 Liquefaction Credit Facilities	100,000			100,000
	CTPL Credit Facility	400,000			400,000
	Total long-term debt	6,585,500			6,585,500
	Long-term debt premium (discount)
	2016 Notes	(12,519		)	(13,693		)
	2021 Sabine Pass Liquefaction Senior Notes	11,222			11,562
	CTPL Credit Facility	(5,853		)	(7,096		)
	Total long-term debt, net of discount	$	6,578,350		$	6,576,273

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information and Disclosures of Non-Cash Transactions (Tables)	3 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures	'
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Three Months Ended March 31,
		2014		2013
	Cash paid during the year for interest, net of amounts capitalized	$	16,567	$	—
	LNG terminal costs funded with accounts payable and accrued liabilities (including affiliate)	67,768		176,488

Net_Income_Loss_per_Common_Uni1

Net Income (Loss) per Common Unit (Tables)	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Schedule of Anticipated Beneficial Conversion Feature impact to Capital Accounts	'
	The following is a schedule by years, based on the capital structure as of March 31, 2014, 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
	2014	(2	)		6		(4	)
	2015	(232	)		781		(549	)
	2016	(29,564	)		99,685		(70,121	)
	2017	(594,390	)		2,004,209		(1,409,819	)
Schedule of Net Income (Loss) per Unit and Allocation of Distribution	'
	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 March 31, 2014
	Net loss		$	(69,733	)
	Declared distributions		24,754			24,259			—		—			495
	Assumed allocation of undistributed net loss		$	(94,487	)	(27,462		)	—		(65,135		)	(1,890		)	—
	Assumed allocation of net loss					$	(3,203	)	$	—	$	(65,135	)	$	(1,395	)	$	—
	Weighted average units outstanding					57,079			145,333		135,384
	Net loss per unit					$	(0.06	)	$	—	$	(0.48	)
	Three Months Ended March 31, 2013
	Net loss		$	(51,733	)
	Declared distributions		24,754			24,259			—		—			495
	Assumed allocation of undistributed net loss		$	(76,487	)	(19,543		)	—		(46,353		)	(1,345		)	(9,246		)
	Assumed allocation of net income (loss)					$	4,716		$	—	$	(46,353	)	$	(850	)	$	(9,246	)
	Assumed allocation of net loss adjusted for the Creole Trail Pipeline Business					$	2,029		$	—	$	(52,727	)	$	(1,035	)
	Weighted average units outstanding					45,547			133,333		135,384
	Net income (loss) per unit					$	0.1		$	—	$	(0.34	)
	Net income (loss) per unit, adjusted to include pre-acquisition date net losses of the Creole Trail Pipeline Business					$	0.04		$	—	$	(0.39	)

Unitholders_Equity_Details

Unitholders' Equity (Details) (USD $)	3 Months Ended			3 Months Ended		12 Months Ended	1 Months Ended	12 Months Ended	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2012	31-May-13	Dec. 31, 2012	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
		Cheniere Energy Partners LP Holdings, LLC [Member]	Blackstone CQP Holdco LP [Member]	Common Units [Member]	Class B Units [Member]	Class B Units [Member]	Class B Units [Member]	Class B Units [Member]	General Partner [Member]	General Partner [Member]	General Partner [Member]
		Rate	Rate			Blackstone CQP Holdco LP [Member]	Cheniere Energy, Inc. [Member]	Cheniere Energy, Inc. [Member]		Minimum [Member]	Maximum [Member]
Class of Stock [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Number of days after quarter end distribution is paid	'45 days	'	'	'	'	'	'	'	'	'	'
Distributions Per Limited Partnership Unit Outstanding, Basic	'	'	'	$0.43	'	'	'	'	'	'	'
Distributions entitled by General Partner, Percentage	'	'	'	'	'	'	'	'	2.00%	'	'
Incentive Distribution, Distribution Per Unit	'	'	'	'	'	'	'	'	'	15.00%	50.00%
Proceeds from Issuance or Sale of Equity	'	'	'	'	'	$1,500	$180	$500	'	'	'
Additional units purchased, shares	'	'	'	'	'	'	12	'	'	'	'
Partnership Units, Conversion Ratio, Quarterly Compounded Rate	'	'	'	'	3.50%	'	'	'	'	'	'
Partnership Units, Accreted Conversion Ratio	'	1.27	1.25	'	'	'	'	'	'	'	'

Restricted_Cash_and_Cash_Equiv1

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

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

31-May-13

Mar. 31, 2014

Sabine Pass LNG, LP [Member]

Sabine Pass LNG, LP [Member]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Cheniere Creole Trail Pipeline LP [Member]

Cheniere Creole Trail Pipeline LP [Member]

2016 Senior Notes [Member]

2016 Senior Notes [Member]

2020 Senior Notes [Member]

2020 Senior Notes [Member]

Senior Notes [Member]

2012 Liquefaction Facility [Member]

2021 Sabine Pass Liquefaction Senior Notes [Member]

2022 Sabine Pass Liquefaction Senior Notes [Member]

2023 Sabine Pass Liquefaction Senior Notes [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

2013 Sabine Pass Liquefaction Credit Facility [Member]

Creole Trail Pipeline Credit Facility [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]

Sabine Pass Liquefaction [Member]

Sabine Pass Liquefaction [Member]

Cheniere Creole Trail Pipeline LP [Member]

Rate

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

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

7.50%

7.50%

6.50%

6.50%

'

'

5.63%

6.25%

5.63%

'

'

'

Debt Instrument, Fixed Charge, Coverage Ratio

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

3,600,000,000

'

'

'

5,900,000,000

5,900,000,000

400,000,000

Current restricted cash and cash equivalents

176,518,000

227,652,000

53,000,000

15,000,000

96,900,000

192,100,000

26,600,000

20,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Non-current restricted cash and cash equivalents

$323,728,000

$1,025,056,000

$76,100,000

$76,100,000

$197,500,000

$867,600,000

$50,100,000

$81,400,000

'

'

'

'

'

'

'

'

'

'

'

'

Property_Plant_and_Equipment_S

Property, Plant and Equipment - Schedule of Capitalized Costs and Fixed Assets (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, net	$7,028,192	$6,383,939
LNG terminal costs [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation	-305,574	-291,265
Property, plant and equipment, net	7,026,812	6,382,837
LNG terminal [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	2,232,495	2,225,412
LNG terminal construction-in-process [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	5,099,744	4,448,541
LNG site and related costs, net [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	147	149
Fixed assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Accumulated depreciation	-3,043	-2,870
Property, plant and equipment, net	1,380	1,102
Computer and office equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	613	612
Vehicles [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	1,306	907
Machinery and equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	1,490	1,490
Other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment, gross	$1,014	$963

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Property, Plant and Equipment [Line Items]	'	'
Depreciation	$14,318,000	$14,304,000	[1]
Sabine Pass LNG terminal [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Depreciation	14,300,000	14,400,000
The Sabine Pass Liquefaction Project [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Capitalized interest expense	$78,800,000	$35,300,000
[1]	Retrospectively adjusted as discussed in Note 1.

Financial_Instruments_Fair_Val

Financial Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'	'	'
Collateral Already Posted, Aggregate Fair Value	$500,000	$900,000	'
LNG Inventory Derivative assets	35,000	'	'
Fuel Derivatives liability	'	-161,000	'
LNG Inventory Derivatives [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Derivative Asset, Fair Value, Gross Asset	35,000	-161,000	'
Derivative Asset, Fair Value, Net	28,000	0	'
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0	'
Derivative, Collateral, Right to Reclaim Cash	0	0	'
Derivative Asset, Fair Value, Amount Offset Against Collateral	7,000	-161,000	'
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	35,000	'	'
Fuel Derivatives liability	'	-161,000	'
Fuel Derivatives [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Derivative Asset, Fair Value, Gross Asset	19,000	27,000	'
Derivative Asset, Fair Value, Net	19,000	27,000	'
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0	'
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0	'
Derivative, Collateral, Right to Reclaim Cash	0	0	'
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
LNG Inventory Derivative assets	0	0	'
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
LNG Inventory Derivative assets	0	0	'
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
LNG Inventory Derivative assets	19,000	27,000	'
Fuel 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	19,000	27,000	'
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Derivative Asset, 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 Asset, Fair Value, Net	51,626,000	84,639,000	'
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Derivative Asset, Fair Value, Net	0	0	'
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member] | Cheniere Marketing, LLC [Member] | LNG Lease Agreement [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
LNG Inventory Derivative assets	2,000	'	200,000
Fuel Derivatives liability	35,000	-161,000	'
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Derivative Asset, Fair Value, Gross Asset	71,170,000	98,123,000	'
Derivative Liability, Fair Value, Net	-19,544,000	-13,484,000	'
Derivative Asset, Fair Value, Net	71,170,000	98,123,000	'
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0	'
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0	'
Derivative, Collateral, Right to Reclaim Cash	0	0	'
Derivative Asset, Fair Value, Amount Offset Against Collateral	0	0	'
Derivative Liability, Fair Value, Gross Liability	-19,544,000	-13,484,000	'
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 Asset, Fair Value, Net	$51,626,000	$84,639,000	'

Financial_Instruments_Fair_Val1

Financial Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]	'	'
Collateral Already Posted, Aggregate Fair Value	$500,000	$900,000
LNG Inventory Derivative assets	35,000	'
Fuel Derivatives liability	'	($161,000)

Financial_Instruments_Derivati

Financial Instruments - Derivative Instruments, Gain (Loss) - Fuel and LNG Inventory Derivatives (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative loss, net	($34,681,000)	($17,468,000)	[1]
Sabine Pass Liquefaction [Member] | LNG Inventory Derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative loss, net	-435,000	0
Cheniere Marketing, LLC [Member] | Fuel Derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative loss, net	242,000	515,000
LNG Lease Agreement [Member] | Cheniere Marketing, LLC [Member] | Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	-29,000	-600,000
Revenues [Member] | LNG Lease Agreement [Member] | Cheniere Marketing, LLC [Member] | Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	($29,000)	($550,000)
[1]	Retrospectively adjusted as discussed in Note 1.

Financial_Instruments_Schedule

Financial Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) (Interest Rate Contract [Member], USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014
		Effective Date August 14, 2012 [Domain]	Noncurrent Derivative Assets [Member]	Noncurrent Derivative Assets [Member]	Other Current Liabilities [Member]	Other Current Liabilities [Member]	Maximum [Member]	Maximum [Member]
			Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]		Effective Date August 14, 2012 [Domain]
Derivative [Line Items]	'	'	'	'	'	'	'	'
Notional Amount of Interest Rate Derivatives	$0	$20	'	'	'	'	$671,000,000	$2,900,000,000
Interest Rate Derivative Assets, at Fair Value	'	'	71,170,000	98,123,000	'	'	'	'
Derivative instrument average fixed rate (percent)	2.05%	1.98%	'	'	'	'	'	'
Debt Instrument, Description of Variable Rate Basis	'One-month LIBOR	'One-month LIBOR	'	'	'	'	'	'
Derivative, Inception Date	5-Jun-13	14-Aug-12	'	'	'	'	'	'
Derivative, Maturity Date	28-May-20	31-Jul-19	'	'	'	'	'	'
Interest Rate Derivative Liabilities, at Fair Value	'	'	'	'	($19,544,000)	($13,484,000)	'	'

Financial_Instruments_Schedule1

Financial Instruments - Schedule of Interest Rate Derivatives (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]	'	'
Collateral Already Posted, Aggregate Fair Value	$500,000	$900,000
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	-19,544,000	-13,484,000
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	$71,170,000	$98,123,000

Financial_Instruments_Schedule2

Financial Instruments - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Details) (USD $)	3 Months Ended				12 Months Ended	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013		Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013
				Interest Rate Contract [Member]	Interest Rate Contract [Member]	Designated as Hedging Instrument [Member]	Designated as Hedging Instrument [Member]
						Interest Rate Contract [Member]	Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]	'	'		'	'	'	'
Change in fair value of interest rate cash flow hedges	$0	$21,297	[1]	'	'	'	'
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	0	0
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	$0	($30)	[1]	'	'	'	'
[1]	Retrospectively adjusted as discussed in Note 1.

Financial_Instruments_Derivati1

Financial Instruments - Derivative Instruments, Gain (Loss) - Interest Rate Derivatives, Not Designated (Details) (Not Designated as Hedging Instrument [Member], Interest Rate Contract [Member], USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
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	($34,479)	($17,983)

Financial_Instruments_Derivati2

Financial Instruments - Derivative Gross Presentation on Consolidated Balance Sheets (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fuel Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Amount Offset Against Collateral	$0	$0
Derivative Asset, Fair Value, Gross Asset	19	27
Derivative Asset, Fair Value, Net	19	27
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	35	-161
Derivative Asset, Fair Value, Amount Offset Against Collateral	7	-161
Derivative Asset, Fair Value, Net	28	0
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	-19,544	-13,484
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0
Derivative Liability, Fair Value, Net	-19,544	-13,484
Derivative Asset, Fair Value, Gross Asset	71,170	98,123
Derivative Asset, Fair Value, Amount Offset Against Collateral	0	0
Derivative Asset, Fair Value, Net	71,170	98,123
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Net	$51,626	$84,639

Financial_Instruments_Schedule3

Financial Instruments - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
2016 Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	$1,652,981	$1,651,807
2016 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	1,824,478	1,868,607
2020 Senior 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 Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	441,000	432,600
2021 Sabine Pass Liquefaction Senior Notes [Member] | Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	2,011,222	2,011,562
2021 Sabine Pass Liquefaction Senior Notes [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Notes Payable, Fair Value Disclosure	2,079,101	1,961,273
2023 Sabine Pass Liquefaction Senior Notes [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	1,000,000
2023 Sabine Pass Liquefaction Senior Notes [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	997,500	935,000
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	100,000
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	100,000
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	394,147	392,904
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	400,000
2022 Sabine Pass Liquefaction Senior Notes [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	1,000,000
2022 Sabine Pass Liquefaction Senior Notes [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	$1,042,500	$982,500

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Payables and Accruals [Abstract]	'	'
Interest and related debt fees	$101,637	$80,151
Liquefaction Project costs	17,642	83,127
LNG terminal costs	1,612	1,612
Other	2,105	5,162
Total accrued liabilities	122,996	170,052
Accrued liabilitiesbaffiliate	25,287	44,384
Total accrued liabilities (including affiliate)	$148,283	$214,436

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	$6,585,500	$6,585,500
Total long-term debt, net of discount	6,578,350	6,576,273
2016 Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	1,665,500	1,665,500
Debt Instrument, Unamortized Discount	-12,519	-13,693
2020 Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	420,000	420,000
2021 Sabine Pass Liquefaction Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	2,000,000	2,000,000
Debt Instrument, Unamortized Premium	11,222	11,562
2022 Sabine Pass Liquefaction Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	1,000,000	1,000,000
2023 Sabine Pass Liquefaction Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	1,000,000	1,000,000
2013 Sabine Pass Liquefaction Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	100,000	100,000
Creole Trail Pipeline Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Long Term Debt, Gross	400,000	400,000
Debt Instrument, Unamortized Discount	($5,853)	($7,096)

LongTerm_Debt_LongTerm_Debt_Sa

Long-Term Debt Long-Term Debt - Sabine Pass LNG Senior Notes (Details) (USD $)	3 Months Ended			3 Months Ended		3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
		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]
		2016 Senior Notes [Member]	2016 Senior Notes [Member]	2020 Senior Notes [Member]	2020 Senior Notes [Member]	Senior Notes [Member]	Senior Notes [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'
Discount rate over Treasury Rate to calculate fair value ratio of redemption price	'	0.50%	'	'	'	'	'
Debt Instrument, Face Amount	'	$1,665,500,000	$1,665,500,000	$420,000,000	$420,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	7.50%	7.50%	6.50%	6.50%	'	'
Debt Instrument, Redemption Price, Percentage	'	100.00%	'	106.50%	'	'	'
Redemption of Debt Instrument, Percentage	'	'	'	35.00%	'	'	'
Percentage of debt principal	'	1.00%	'	'	'	'	'
Redemption of Debt Instrument, Period	'	'	'	'180 days	'	'	'
Percentage if 2020 Notes Outstanding	'	'	'	65.00%	'	'	'
Partners' Capital Account, Distributions	$24,754,000	'	'	'	'	$63,400,000	$76,700,000

LongTerm_Debt_LongTerm_Debt_Sa1

Long-Term Debt Long-Term Debt - Sabine Pass Liquefaction Senior Notes (Details) (Sabine Pass Liquefaction [Member], USD $)	3 Months Ended
	Mar. 31, 2014
	Rate
2021 Sabine Pass Liquefaction Senior Notes [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%
2023 Sabine Pass Liquefaction Senior Notes [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%
Sabine Pass Liquefaction Senior Notes [Domain]	'
Debt Instrument [Line Items]	'
Debt Instrument, Interest Rate, Stated Percentage	5.63%
Debt Instrument, Fixed Charge, Coverage Ratio Period	'12 months
Debt Instrument, Fixed Charge, Coverage Ratio	1.25
Debt Instrument, Redemption Price, Percentage	100.00%
2022 Sabine Pass Liquefaction Senior Notes [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%

LongTerm_Debt_LongTerm_Debt_20

Long-Term Debt Long-Term Debt - 2013 Liquefaction Credit Facility (Details) (USD $)	1 Months Ended	3 Months Ended
	Nov. 30, 2013	Mar. 31, 2014	Dec. 31, 2013	31-May-13
2013 Sabine Pass Liquefaction Credit Facility [Member] | Sabine Pass Liquefaction [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity	'	$5,900,000,000	'	$5,900,000,000
Line of Credit Facility, Amount Outstanding	'	100,000,000	'	'
Line of Credit Facility, Remaining Borrowing Capacity	'	4,900,000,000	4,900,000,000	'
Line of Credit Facility, Increase (Decrease), Net	885,000,000	'	'	'
Line of Credit Facility, Collateral Fees, Amount	'	144,000,000	'	'
Line of Credit Facility, Commitment Fee Percentage	'	40.00%	'	'
Line of Credit Facility, Amortization Period	'	'18 years 0 months	'	'
2022 Sabine Pass Liquefaction Senior Notes [Member] | Sabine Pass Liquefaction [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Gains (Losses) on Extinguishment of Debt	'	43,300,000	'	'
Proceeds from Issuance of Long-term Debt	'	$978,000,000	'	'
Line of Credit [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Debt Instrument, Description of Variable Rate Basis	'	'LIBOR	'	'
Minimum [Member] | 2013 Sabine Pass Liquefaction Credit Facility [Member] | Sabine Pass Liquefaction [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Percentage of Debt Hedged by Interest Rate Derivatives	'	75.00%	'	'
Minimum [Member] | 2013 Liquifaction Credit Facilities - LIBOR Loans [Member] [Member] | Construction [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Debt Instrument, Basis Spread on Variable Rate	'	2.30%	'	'
Maximum [Member] | 2013 Liquifaction Credit Facilities - LIBOR Loans [Member] [Member] | Construction [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Debt Instrument, Basis Spread on Variable Rate	'	3.00%	'	'
Maximum [Member] | 2013 Liquifaction Credit Facilities - LIBOR Loans [Member] [Member] | Operations [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Debt Instrument, Basis Spread on Variable Rate	'	3.25%	'	'

LongTerm_Debt_LongTerm_Debt_201

Long-Term Debt Long-Term Debt - 2012 Liquefaction Credit Facility (Details) (Sabine Pass Liquefaction [Member], USD $)	Jun. 30, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
In Millions, unless otherwise specified	Liquefaction Credit Facility [Member]	Liquefaction Credit Facility [Member]	Construction [Member]	Operations [Member]
		Minimum [Member]	2012 Liquifaction Credit Facility - LIBOR Loans [Member]	2012 Liquifaction Credit Facility - LIBOR Loans [Member]
Debt Instrument [Line Items]	'	'	'	'
Debt Instrument, Basis Spread on Variable Rate	'	'	3.50%	3.75%
Line of Credit Facility, Amount Outstanding	$100	'	'	'
Percentage of Debt Hedged by Interest Rate Derivatives	'	75.00%	'	'

LongTerm_Debt_LongTerm_Debt_CT

Long-Term Debt Long-Term Debt - CTPL Credit Facility (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified	Creole Trail Pipeline Credit Facility [Member]	Creole Trail Pipeline Credit Facility [Member]	Creole Trail Pipeline Credit Facility - LIBOR Loans [Member]	Line of Credit [Member]	Cheniere Creole Trail Pipeline LP [Member]
					Creole Trail Pipeline Credit Facility [Member]
Debt Instrument [Line Items]	'	'	'	'	'
Debt Instrument, Unamortized Discount	$5,853	$7,096	'	'	$10,000
Debt Instrument, Description of Variable Rate Basis	'	'	'	'LIBOR	'
Debt Instrument, Basis Spread on Variable Rate	'	'	3.25%	'	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

3 Months Ended

3 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Cooperative Endeavor Agreements [Member]

Sabine Pass Tug Services, LLC [Member]

Sabine Pass Tug Services, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [Member]

Cheniere Energy Investments, LLC [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 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]

Cheniere Energy Partners, LP [Member]

Tug Boat Lease Sharing Agreement [Member]

Tug Boat Lease Sharing Agreement [Member]

LNG Lease Agreement [Member]

LNG Lease Agreement [Member]

LNG Terminal Capacity Agreements [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

LNG Inventory Derivatives [Member]

Management Services Agreement [Member]

Operation and Maintenance Agreement [Member]

Management Services Agreement [Member]

LNG Sale and Purchase Agreement [Member]

LNG Sale and Purchase Agreement [Member]

LNG Sale and Purchase Agreement [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Operation and Maintenance Agreement [Member]

Management Services Agreement [Member]

Contracts for Sale and Purchase of Natural Gas and LNG [Member]

Contracts for Sale and Purchase of Natural Gas and LNG [Member]

Contracts for Sale and Purchase of Natural Gas and LNG [Member]

Contracts for Sale and Purchase of Natural Gas and LNG [Member]

LNG Terminal Capacity Agreements [Member]

Service Agreements [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

LNG Lease Agreement [Member]

LNG Lease Agreement [Member]

LNG Lease Agreement [Member]

Revenues [Member]

Revenues [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cooperative Endeavor Agreements [Member]

Cooperative Endeavor Agreements [Member]

Cheniere Energy, Inc. [Member]

Cheniere LNG Terminals, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Energy, Inc. [Member]

Cheniere Energy, Inc. [Member]

Sabine Pass Liquefaction [Member]

Cheniere LNG Terminals, LLC [Member]

MMBTU

MMBTU

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

LNG Lease Agreement [Member]

LNG Lease Agreement [Member]

MMBTU

Profit Category One [Member]

Profit Category Two [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas And Liquefied Natural Gas [Member]

Natural Gas And Liquefied Natural Gas [Member]

bcf

Cheniere Marketing, LLC [Member]

Cheniere Marketing, LLC [Member]

MMBTU

MMBTU

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Advances to Affiliate Current

$12,857,000

'

$14,737,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regasification capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

Related Party Transactions, Commitments, Annual Reservation Fee Payment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000,000

'

Terminal Use Agreement Maintenance Expense

-500,000

-300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds (Payments) of Gross Margin Earned, Percentage

'

'

'

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

20.00%

'

'

'

'

'

'

'

'

'

'

Purchase Commitment, Excess And Uncommitted LNG Produced

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

104,000,000

36,000,000

68,000,000

'

'

'

'

'

'

'

'

'

'

Incremental LNG Volume, Purchase Price Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

115.00%

'

'

'

'

'

'

'

'

'

'

'

Incremental LNG Volume, Purchase Price Per MMBtu

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

Liquefied Natural Gas Inventory

'

'

'

'

'

'

10,500

41,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LNG inventory related party

'

'

'

'

'

'

34,000

130,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LNG Inventory Derivative assets

35,000

'

'

'

'

'

'

'

'

2,000

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Gain (Loss) on Derivative, Net

'

'

'

'

'

'

'

'

'

29,000

600,000

'

29,000

550,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and Administrative Expense Related Parties

27,153,000

23,216,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,800,000

Operating and maintenance expensebaffiliate

4,431,000

6,923,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Committed Monthly Fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

83,333

541,667

'

'

'

'

'

130,000

520,000

'

'

'

'

'

'

Related Party Transaction, Bonus Percentage Entitled Upon Meeting Certain Criteria

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

Proceeds (Payments) Of Capital Expenditures Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

0.60%

2.40%

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate commitment under the Agreement

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due from Related Parties, Noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

19,600,000

17,200,000

'

'

'

'

'

'

'

'

Related Party Transaction, Purchases from Related Party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

900,000

'

'

Revenuesbaffiliate

$772,000

$545,000

[1]

'

'

$700,000

$700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

$900,000

'

'

'

'

[1]

Retrospectively adjusted as discussed in Note 1.

Supplmental_Cash_Flow_Informat

Supplmental Cash Flow Information and Disclosures of Non-Cash Transactions (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'	'
Cash paid during the year for interest, net of amounts capitalized	$16,567	$0
LNG terminal costs funded with accounts payable and accrued liabilities (including affiliate)	$67,768	$176,488

Net_Income_Loss_per_Common_Uni2

Net Income (Loss) per Common Unit (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2014
Cheniere Energy Partners LP Holdings, LLC [Member] | Effective Yield Method [Member]	'
Distribution Made to Member or Limited Partner [Line Items]	'
Amortization of Beneficial Conversion Feature of Class B Units	888.70%
Blackstone CQP Holdco LP [Member] | Effective Yield Method [Member]	'
Distribution Made to Member or Limited Partner [Line Items]	'
Amortization of Beneficial Conversion Feature of Class B Units	966.10%
Common Units [Member]	'
Distribution Made to Member or Limited Partner [Line Items]	'
Distribution Made to Member or Limited Partner, Distributions Paid, Per Unit	0.425
Class B Units [Member]	'
Distribution Made to Member or Limited Partner [Line Items]	'
Discount upon issuance of Class B units representating beneficial conversion feature	2,130

Net_Income_Loss_per_Common_Uni3

Net Income (Loss) per Common Unit - Schedule of Anticipated Beneficial Conversion Feature impact to Capital Accounts (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014
Common Units [Member]	'
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Next Twelve Months	($2)
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Two	-232
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Three	-29,564
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Four	-594,390
Class B Units [Member]	'
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Next Twelve Months	6
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Two	781
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Three	99,685
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Four	2,004,209
Subordinated Units [Member]	'
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Next Twelve Months	-4
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Two	-549
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Three	-70,121
Amortization of Beneficial Conversion Feature - Impact to Capital Accounts, Year Four	($1,409,819)

Net_Income_Loss_per_Common_Uni4

Net Income (Loss) per Common Unit - Schedule of Net Income (Loss) per Unit and Allocation of Distribution (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Net loss	($69,733)	($51,733)	[1]
Declared distributions	24,754	24,754
Assumed allocation of undistributed net loss	-94,487	-76,487
Weighted average units outstanding	57,079	45,547	[1]
Net income (loss) per unit	($0.06)	$0.10	[1]
Net loss attributable to the Creole Trail Pipeline Business	0	-9,246	[1]
Common Units [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Declared distributions	24,259	24,259
Assumed allocation of undistributed net loss	-27,462	-19,543
Assumed allocation of net income (loss)	-3,203	4,716
Common Units [Member] | Creole Trail Pipeline Business [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Assumed allocation of net income (loss)	'	2,029
Net income (loss) per unit	'	$0.04
Class B Units [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Declared distributions	0	0
Assumed allocation of undistributed net loss	0	0
Assumed allocation of net income (loss)	0	0
Weighted average units outstanding	145,333	133,333
Net income (loss) per unit	$0	$0
Class B Units [Member] | Creole Trail Pipeline Business [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Assumed allocation of net income (loss)	'	0
Net income (loss) per unit	'	$0
Subordinated Units [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Declared distributions	0	0
Assumed allocation of undistributed net loss	-65,135	-46,353
Assumed allocation of net income (loss)	-65,135	-46,353
Weighted average units outstanding	135,384	135,384
Net income (loss) per unit	($0.48)	($0.34)
Subordinated Units [Member] | Creole Trail Pipeline Business [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Assumed allocation of net income (loss)	'	-52,727
Net income (loss) per unit	'	($0.39)
General Partner [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Declared distributions	495	495
Assumed allocation of undistributed net loss	-1,890	-1,345
Assumed allocation of net income (loss)	-1,395	-850
General Partner [Member] | Creole Trail Pipeline Business [Member]	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'
Assumed allocation of net income (loss)	'	($1,035)
[1]	Retrospectively adjusted as discussed in Note 1.