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

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Central Index Key	1499200
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding	0
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float		$0

Balance_Sheets

Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$0	$0
Restricted cash and cash equivalents	155,810	192,144
Accounts receivable—affiliate	2,750	1,167
Advances to affiliate	23,969	9,430
Prepaid expenses and other	3,541	4,390
Other—affiliate	153	121
Total current assets	186,223	207,252
Non-current restricted cash and cash equivalents	457,053	867,590
Property, plant and equipment, net	6,962,395	4,412,580
Debt issuance costs, net	228,913	296,040
Non-current derivative assets	11,744	98,123
Other non-current assets	99,417	60,387
Total assets	7,945,745	5,941,972
Current liabilities
Accounts payable	5,974	8,067
Accrued liabilities	113,538	144,575
Due to affiliates	13,051	26,019
Derivative liabilities	23,247	13,484
Total current liabilities	155,810	192,145
Long-term debt, net	6,517,266	4,111,562
Non-current derivative liabilities	268	0
Commitments and contingencies
Member’s equity	1,272,401	1,638,265
Total liabilities and member’s equity	$7,945,745	$5,941,972

Statements_of_Operations

Statements of Operations (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement [Abstract]
Revenues	$0	$0	$0
Expenses
Development expense	9,319	11,540	37,341
Development expense—affiliate	1,153	1,392	2,955
General and administrative expense	5,305	3,305	1,359
General and administrative expense—affiliate	71,065	93,064	33,951
Terminal use agreement maintenance expense	25,677	26,228	10,058
Terminal use agreement maintenance expense—affiliate	387	394	0
Depreciation expense	967	213	119
Operating and maintenance expense	6,071	0	0
Operating and maintenance expense—affiliate	95	0	0
Total expenses	120,039	136,136	85,783
Loss from operations	-120,039	-136,136	-85,783
Other income (expense)
Interest expense, net	-23,909	-10,796	-139
Loss on early extinguishment of debt	-114,335	-131,576	0
Derivative gain (loss), net	-118,541	83,266	679
Other income (expense)	-29	752	86
Total other income (expense)	-256,814	-58,354	626
Net loss	($376,853)	($194,490)	($85,157)

Statements_of_Comprehensive_Lo

Statements of Comprehensive Loss (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Comprehensive Income [Abstract]
Net loss	($376,853)	($194,490)	($85,157)
Other comprehensive income (loss)
Loss on settlements of interest rate cash flow hedges retained in other comprehensive income	0	-30	-136
Change in fair value of interest rate cash flow hedges	0	21,297	-27,104
Losses reclassified into earnings as a result of discontinuance of cash flow hedge accounting	0	5,973	0
Total other comprehensive income (loss)	0	27,240	-27,240
Comprehensive loss	($376,853)	($167,250)	($112,397)

Statements_of_Members_Equity_D

Statements of Member's Equity (Deficit) (USD $)	Total	Sabine Pass LNG-LP, LLC [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
In Thousands, unless otherwise specified
Members' equity, beginning of period at Dec. 31, 2011	($46,380)	($46,380)	$0
Increase (Decrease) in Partners' Capital [Roll Forward]
Contributions from Cheniere Partners	1,623,849	1,623,849	0
Non-cash contributions from Cheniere Partners	2,167	2,167	0
Interest rate cash flow hedges	-27,240	0	-27,240
Net loss	-85,157	-85,157	0
Member's equity, end of period at Dec. 31, 2012	1,467,239	1,494,479	-27,240
Increase (Decrease) in Partners' Capital [Roll Forward]
Contributions from Cheniere Partners	338,276	338,276	0
Interest rate cash flow hedges	27,240	0	27,240
Net loss	-194,490	-194,490	0
Member's equity, end of period at Dec. 31, 2013	1,638,265	1,638,265	0
Increase (Decrease) in Partners' Capital [Roll Forward]
Contributions from Cheniere Partners	11,734	11,734	0
Non-cash contributions to limited partner	-745	-745	0
Net loss	-376,853	-376,853	0
Member's equity, end of period at Dec. 31, 2014	$1,272,401	$1,272,401	$0

Statements_of_Cash_Flows

Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net loss	($376,853)	($194,490)	($85,157)
Adjustments to reconcile net loss to net cash used in operating activities:
Use of restricted cash and cash equivalents for certain operating activities	175,853	161,065	80,764
Depreciation	967	2,917	119
Non-cash terminal use agreement maintenance expense	24,461	26,731	9,612
Total (gains) losses on derivatives, net	118,199	-84,299	-679
Net cash from settlement of derivative instruments	-22,093	632	0
Loss on extinguishment of debt	114,335	131,576	0
Changes in operating assets and liabilities:
LNG inventory	-22,963	0	0
Accounts payable and accrued liabilities	9,234	-167	-1,781
Due to affiliates	-2,373	1,665	11,545
Advances to affiliate	-14,539	-5,017	-4,414
Other, net	-2,644	-39,446	-10,009
Other, net—affiliate	-1,584	-1,167	0
Net cash provided by (used in) operating activities	0	0	0
Cash flows from investing activities
Property, plant and equipment, net	-2,548,855	-3,082,195	-1,113,999
Use of restricted cash and cash equivalents for the acquisition of property, plant and equipment	2,587,565	3,092,025	1,114,742
Other	-38,710	-9,830	-743
Net cash provided by (used in) investing activities	0	0	0
Cash flows from financing activities
Proceeds from issuances of long-term debt	2,584,500	4,112,500	100,000
Repayments of long-term debt	-177,000	-100,000	0
Contributions from Cheniere Partners	11,734	338,276	1,623,849
Investment in restricted cash and cash equivalents	-2,316,547	-4,041,372	-1,466,958
Debt issuance and deferred financing costs	-102,687	-309,404	-212,412
Advances—affiliate	0	0	-44,479
Net cash provided by (used in) financing activities	0	0	0
Net increase (decrease) in cash and cash equivalents	0	0	0
Cash and cash equivalents—beginning of period	0	0	0
Cash and cash equivalents—end of period	$0	$0	$0

Organization_and_Nature_of_Ope

Organization and Nature of Operations (Notes)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	ORGANIZATION AND NATURE OF OPERATIONS
	We are a Delaware limited liability company formed by Cheniere Energy Partners, L.P. (“Cheniere Partners”) in June 2010 to own, develop and operate natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) at the Sabine Pass LNG terminal (the “Sabine Pass LNG terminal”) adjacent to the existing regasification facilities owned and operated by Sabine Pass LNG, L.P. (“Sabine Pass LNG”). We are a Houston-based company with one member, Sabine Pass LNG-LP, LLC, an indirect wholly owned subsidiary of Cheniere Partners. We and Sabine Pass LNG are each indirect wholly owned subsidiaries of Cheniere Energy Investments, LLC (“Cheniere Investments”), which is a wholly owned subsidiary of Cheniere Partners. Cheniere Partners is a publicly traded limited partnership (NYSE MKT: CQP) formed in November 2006 and is 55.9% owned subsidiary of Cheniere Energy Partners LP Holdings, LLC, which is in turn an 80.1% owned subsidiary of Cheniere Energy, Inc. (“Cheniere”), a Houston-based energy company primarily engaged in LNG-related businesses.
	Our Liquefaction Project is being developed at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. The Sabine Pass LNG terminal is located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast and includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d. We plan to construct up to six Trains, which are in various stages of development. Each train is expected to have nominal production capacity of approximately 4.5 mtpa of LNG.
	In June 2014, the Financial Accounting Standards Board (“FASB”) amended its guidance on development stage entities. The amendment removed all incremental financial reporting requirements from generally accepted accounting principles in the United States (“GAAP”) for development stage entities. This guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. We adopted this guidance in the quarterly period ended June 30, 2014. Prior to our adoption of this guidance, we were a development stage entity because we devote substantially all of our efforts to establishing a new natural gas liquefaction business for which planned principal operations have not commenced. The adoption of this guidance did not have a material impact on our financial position, results of operations or cash flows other than the removal of inception-to-date information about income statement line items, cash flows and equity transactions.
	Unless the context requires otherwise, references to “we,” “us,” “our,” the “Company,” or “Sabine Pass Liquefaction” are intended to refer to Sabine Pass Liquefaction.

Summary_of_Significant_Account

Summary of Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Basis of Presentation
	Our Financial Statements were prepared in accordance with GAAP. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows.
	Use of Estimates
	The preparation of Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
	Fair Value
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.
	In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates.
	Recurring fair-value measurements are performed for commodity derivatives and interest-rate derivatives as disclosed in Note 5—Derivative Instruments. The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 7—Long-Term Debt, are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments. Non-financial assets and liabilities initially measured at fair value include intangible assets and AROs.
	Cash and Cash Equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
	Restricted Cash and Cash Equivalents
	Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets.
	Amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal and will not become available to us as cash and cash equivalents. For these amounts, we have presented increases and decreases as “investments in (uses of) restricted cash and cash equivalents” in our Statements of Cash Flows. These amounts that represent non-cash transactions within our Statements of Cash Flows present the effect of sources and uses of restricted cash and cash equivalents as they relate to the changes to assets and liabilities in our Balance Sheets. Restricted cash and cash equivalents are presented on a gross basis within each of those categories so as to reconcile the change in non-cash activity that occurs on the balance sheet from period to period.
	LNG Inventory
	LNG inventory is recorded at cost and is subject to lower of cost or market (“LCM”) adjustments at the end of each period. LNG inventory cost is determined using the average cost method. Terminal use agreement maintenance expense—affiliate represents the amount recorded related to the reimbursement to Sabine Pass LNG of a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal.
	Accounting for LNG Activities
	Generally, we begin capitalizing the costs of a Train once it meets the following criteria: (i) regulatory approval has been received, (ii) financing for the Train is available and (iii) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a Train are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals, and other preliminary investigation and development activities related to the Train.
	Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as intangible LNG assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed.
	We capitalize interest and other related debt costs during the construction period of a Train. Upon commencement of operations, capitalized interest, as a component of the total cost, will be amortized over the estimated useful life of the asset.
	Property, Plant and Equipment
	Property, plant and equipment are recorded at cost. Expenditures for construction activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses.
	Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. In performing this test, an undiscounted cash flow analysis is performed at the lowest level for which identifiable cash flows are independent of cash flows from other assets. If the sum of the undiscounted future net cash flows is less than the net book value of the property, an impairment loss is recognized for the excess, if any, of the property’s net book value over its estimated fair value.  We have recorded no impairments related to property, plant and equipment for 2014, 2013 and 2012.
	Derivative Instruments
	We use derivative instruments to hedge our exposure to cash-flow variability from commodity price and interest rate risk.
	Derivative instruments are recorded at fair value and included in the balance sheet as assets or liabilities depending on the derivative position and the expected timing of settlement. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis.
	Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did not have any derivative instruments designated as cash flow hedges as of December 31, 2014 and 2013.
	From time to time we have elected cash flow hedge accounting for derivatives that we use to hedge the exposure to volatility in floating-rate interest payments. Changes in fair value of derivative instruments designated as cash flow hedges, to the extent the hedge is effective, are recognized in accumulated other comprehensive loss on our Balance Sheets. We reclassify gains and losses on the hedges from accumulated other comprehensive loss into interest expense in our Statements of Operations as the hedged item is recognized. Any change in the fair value resulting from ineffectiveness is recognized immediately as derivative gain (loss) on our Statements of Operations. We use regression analysis to determine whether we expect a derivative to be highly effective as a cash flow hedge prior to electing hedge accounting and also to determine whether all derivatives designated as cash flow hedges have been effective. We perform these effectiveness tests prior to designation for all new hedges and on a quarterly basis for all existing hedges. We calculate the actual amount of ineffectiveness on our cash flow hedges using the “dollar offset” method, which compares changes in the expected cash flows of the hedged transaction to changes in the value of expected cash flows from the hedge. We discontinue hedge accounting when our effectiveness tests indicate that a derivative is no longer highly effective as a hedge; when the derivative expires or is sold, terminated or exercised; when the hedged item matures, is sold or repaid; or when we determine that the occurrence of the hedged forecasted transaction is not probable. When we discontinue hedge accounting but continue to hold the derivative, prospective changes in fair value of the derivative instrument are recorded in income. Once we conclude that the hedged forecasted transaction becomes probable of not occurring, the amount remaining in accumulated other comprehensive loss pertaining to the previously designated derivatives is reclassified out of accumulated other comprehensive loss and into income.
	See Note 5—Derivative Instruments of our Notes to Financial Statements for additional details about our derivative instruments.
	Concentration of Credit Risk
	Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date.
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as an other current asset and not netted within the derivative fair value. Our interest rate derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments.
	We have entered into six fixed-price 20-year SPAs with six unaffiliated third parties. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective SPAs.
	Long-Term Debt
	Our debt consists of long-term secured debt securities and credit facilities with banks and other lenders.  Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors.
	Debt is recorded on our balance sheet at par value adjusted for unamortized discount or premium. Discounts, premiums and costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Statements of Operations.
	Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as debt issuance costs on our Balance Sheets and are being amortized to interest expense or property, plant and equipment over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off to loss on early extinguishment of debt.
	Asset Retirement Obligations
	We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our recognition of AROs is described below.
	Currently, the liquefaction facilities under construction at the Sabine Pass LNG terminal adjacent to the existing regasification facilities are our only long-lived asset. Based on the real property lease agreements and sublease agreements at the Sabine Pass LNG terminal, at the expiration of the term of the leases we are required to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease and sublease agreements have terms of up to 90 years including renewal options. We have determined that the cost to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero. Therefore, we have not recorded an ARO associated with the liquefaction facilities at the Sabine Pass LNG terminal.
	Income Taxes
	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.
	At December 31, 2014, the tax basis of our assets and liabilities was $303.9 million more than the reported amounts of our assets and liabilities.
	Pursuant to the indentures governing our long-term debt, we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the state tax sharing agreement discussed immediately below. The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
	In August 2012, we entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were computed on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.

Restricted_Cash_and_Cash_Equiv

Restricted Cash and Cash Equivalents (Notes)	12 Months Ended
	Dec. 31, 2014
Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS
	Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets.
	In July 2012, we entered into a construction/term loan facility in an amount up to $3.6 billion (the “2012 Liquefaction Credit Facility”). During 2013, we entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 Liquefaction Credit Facilities”), which amended and restated the 2012 Liquefaction Credit Facility. See Note 7—Long-Term Debt. Under the terms and conditions of the 2012 Liquefaction Credit Facility we were required, and under the 2013 Liquefaction Credit Facilities we are required, to deposit all cash received into reserve accounts controlled by a collateral trustee. Therefore, all of our cash and cash equivalents are shown as restricted cash and cash equivalents on our Balance Sheets.
	During 2013, we issued an aggregate principal amount of $2.0 billion, before premium, of 5.625% Senior Secured Notes due 2021 (the “2021 Senior Notes”), $1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 Senior Notes”) and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the “2023 Senior Notes”). During 2014, we issued an aggregate principal amount of $2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 Senior Notes” and collectively with the 2021 Senior Notes, the 2022 Senior Notes and the 2023 Senior Notes, the “Senior Notes”) and additional 2023 Senior Notes (the “Additional 2023 Senior Notes”) in an aggregate principal amount of $0.5 billion, before premium.
	As of December 31, 2014 and 2013, we classified $155.8 million and $192.1 million, respectively, as current restricted cash and cash equivalents for the payment of current liabilities related to the Liquefaction Project and $457.1 million and $867.6 million, respectively, as non-current restricted cash and cash equivalents for future Liquefaction Project construction costs.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	12,821		$	98
	LNG terminal construction-in-process	6,946,242			4,412,077
	Accumulated depreciation	(260		)	—
	Total LNG terminal costs, net	6,958,803			4,412,175
	Fixed assets
	Vehicles	854			309
	Furniture and fixtures	1,154			10
	Machinery and equipment	339			301
	Other	2,292			125
	Accumulated depreciation	(1,047		)	(340		)
	Total fixed assets, net	3,592			405
	Property, plant and equipment, net	$	6,962,395		$	4,412,580

Derivative_Instruments_Notes

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS
	Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly owned subsidiary of Cheniere, has entered into the following derivative instruments, on our behalf, that are reported at fair value:
	•	commodity derivatives to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory (“LNG Inventory Derivatives”);
	•	commodity derivatives consisting of natural gas purchase agreements to secure natural gas feedstock for the Liquefaction Project (“Term Gas Supply Derivatives”); and
	•	interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities (“Interest Rate Derivatives”).
	The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of December 31, 2014 and 2013, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		31-Dec-14															31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total			Quoted Prices in Active Markets			Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)		Total
		(Level 1)															(Level 1)
	LNG Inventory Derivatives asset (liability)	$	—			$	1,071			$	—			$	1,071		$	—		$	(156	)		$	—	$	(156	)
	Term Gas Supply Derivatives asset	—				—				342				342			—			—				—		—
	Interest Rate Derivatives asset (liability)	—				(12,036		)		—				(12,036		)	—			84,639				—		84,639
	The estimated fair values of our LNG Inventory Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data.
	The fair value of our Term Gas Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of our Term Gas Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of the Term Gas Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a particular Term Gas Supply Derivative contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. Internal fair value models that include contractual pricing with a fixed basis include fixed basis amounts for delivery at locations for which no market currently exists. Internal fair value models also include conditions precedent to the respective long-term natural gas purchase agreements. As of December 31, 2014, the majority of our Term Gas Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow and our internal fair value models were based on a market price that equated to our own contractual pricing due to the inactive and unobservable market as well as the conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of the Term Gas Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. We estimated the fair value of our Term Gas Supply Derivatives to be $0.3 million as of December 31, 2014.
	There were no transfers into or out of Level 3 for the years ended December 31, 2014 and 2013. As all of our Term Gas Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs as of December 31, 2014:
			Net Fair Value Asset		Valuation Technique		Significant Unobservable Input		Significant Unobservable Inputs Range
	Term Gas Supply Derivatives		$342		Basis Spread plus Liquid Location		Basis Spread		$ (0.350) - $0.035
	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 our commodity derivatives as either assets or liabilities and measure those instruments at fair value. The changes in the fair value of our commodity derivatives are reported in earnings.
	The following table (in thousands) shows the fair value and location of our commodity derivatives on our Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			December 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	1,071			$	156
	Term Gas Supply Derivatives asset	Prepaid expenses and other			76				—
	Term Gas Supply Derivatives asset	Non-current derivative assets			586				—
	Term Gas Supply Derivatives liability	Derivative liabilities			(53		)		—
	Term Gas Supply Derivatives liability	Non-current derivative liabilities			(267		)		—
	The following table (in thousands) shows the changes in the fair value and settlements of our Commodity Derivatives recorded on our Statements of Operations during the years ended December 31, 2014, 2013 and 2012:
			Year Ended December 31,
		Statement of Operation Location	2014				2013				2012
	LNG Inventory Derivatives gain	Derivative gain (loss), net	$	860			$	476			$	—
	Term Gas Supply Derivatives gain (1)	Operating and maintenance expense	342				—				—
	(1)    There were no settlements during the reporting period.
	LNG Inventory Derivatives
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances where our LNG Inventory Derivatives are in an asset position. Our LNG Inventory Derivatives are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our LNG Inventory Derivatives activities. We had a collateral call of $1.0 million and a collateral deposit of $0.2 million for such contracts, which have not been reflected in the derivative fair value tables but are included in prepaid expenses and other current assets in our Balance Sheets as of December 31, 2014 and 2013, respectively.
	Term Gas Supply Derivatives
	We have entered into index-based physical natural gas supply contracts to secure natural gas feedstock for the Liquefaction Project. The terms of these contracts range from approximately one to seven years and commence upon the occurrence of conditions precedent, including the date of first commercial operation of specified Trains of the Liquefaction Project. We recognize our Term Gas Supply Derivatives as either assets or liabilities and measure those instruments at fair value.  Changes in the fair value of our Term Gas Supply Derivatives are reported in earnings.
	As of December 31, 2014, the majority our Term Gas Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow and our internal fair value models were based on a market price that equated to our own contractual pricing due to the inactive and unobservable market as well as the conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. As of December 31, 2014, the forward notional natural gas buy position of our Term Gas Supply Derivatives was approximately 1,249.4 million MMBtu.
	Interest Rate Derivatives
	In August 2012 and June 2013, we entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, respectively. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2013 Liquefaction Credit Facilities.
	We designated the Interest Rate Derivatives entered into in August 2012 as hedging instruments, which was required in order to qualify for cash flow hedge accounting. As a result of this cash flow hedge designation, we recognized the Interest Rate Derivatives entered into in August 2012 as an asset or liability at fair value and reflected changes in fair value through other comprehensive income in our Statements of Comprehensive Loss.
	Any hedge ineffectiveness associated with the Interest Rate Derivatives entered into in August 2012 was recorded immediately as derivative gain (loss) in our Statements of Operations.  The realized gain (loss) on the Interest Rate Derivatives entered into in August 2012 was recorded as an (increase) decrease in interest expense on our Statements of Operations to the extent not capitalized as part of the Liquefaction Project. The effective portion of the gains or losses on our Interest Rate Derivatives entered into in August 2012 recorded in other comprehensive income would have been reclassified to earnings as interest payments on the 2012 Liquefaction Credit Facility impact earnings. In addition, amounts recorded in other comprehensive income are also reclassified into earnings if it becomes probable that the hedged forecasted transaction will not occur.
	We did not elect to designate the Interest Rate Derivatives entered into in June 2013 as cash flow hedging instruments, and changes in fair value are recorded as derivative gain (loss) within our Statements of Operations.
	During the first quarter of 2013, we determined that it was no longer probable that the forecasted variable interest payments on the 2012 Liquefaction Credit Facility would occur in the time period originally specified based on the continued development of our financing strategy for the Liquefaction Project, and, in particular, the Senior Notes described in Note 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 are recorded as other comprehensive income (loss) within our Balance Sheets, and changes in fair value subsequent to their de-designation date are recorded as derivative gain (loss) within our Statements of Operations.
	In June 2013, we concluded that the hedged forecasted transactions associated with the Interest Rate Derivatives entered into in connection with the 2012 Liquefaction Credit Facility had become probable of not occurring based on the issuances of the Senior Notes, the closing of the 2013 Liquefaction Credit Facilities, the additional Interest Rate Derivatives executed in June 2013, and our intention to continue to issue fixed rate debt to refinance the 2013 Liquefaction Credit Facilities. As a result, the amount remaining in accumulated other comprehensive income (“AOCI”) pertaining to the previously designated Interest Rate Derivatives was reclassified out of AOCI and into income. We have presented the changes in fair value and settlements subsequent to the reclassification date separate from interest expense as derivative gain (loss), net in our Statements of Operations.
	In May 2014, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $9.3 million within our Statements of Operations in conjunction with the termination of approximately $2.1 billion of commitments under the 2013 Liquefaction Credit Facilities as discussed in Note 7—Long-Term Debt.
	At December 31, 2014, we had the following Interest Rate Derivatives outstanding:
			Initial Notional Amount		Maximum Notional Amount		Effective Date		Maturity Date		Weighted Average Fixed Interest Rate Paid		Variable Interest Rate Received
	Interest Rate Derivatives - Not Designated		$20.0 million		$2.5 billion		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
	The following table (in thousands) shows the fair value of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		December 31, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	11,158			$	98,123
	Interest Rate Derivatives - Not Designated		Derivative liabilities		(23,194		)		(13,484		)
	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income (“OCI”) and AOCI for the years ended December 31, 2014, 2013 and 2012:
			Gain (Loss) in OCI				Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	31-Dec-12
	Interest Rate Derivatives - Designated		$	(21,290	)		$	—			$	—
	Interest Rate Derivatives - De-designated		(5,814		)		—				—
	Interest Rate Derivatives - Settlements		(136		)		—				—
	31-Dec-13
	Interest Rate Derivatives - Designated		21,297				—				5,807
Interest Rate Derivatives - Settlements		(30		)		—				166
31-Dec-14
Interest Rate Derivatives - Designated		—				—				—
Interest Rate Derivatives - De-designated		—				—				—
Interest Rate Derivatives - Settlements		—				—				—
The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Statements of Operations during the years ended December 31, 2014, 2013 and 2012:
	Year Ended December 31,
	2014				2013				2012
Interest Rate Derivatives - Not Designated	$	(119,401	)		$	88,596			$	679
Balance Sheet Presentation
Our commodity and interest rate derivatives are presented on a net basis on our Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
		Gross Amounts Recognized				Gross Amounts Offset in the Balance Sheets				Net Amounts Presented in the Balance Sheets				Gross Amounts Not Offset in the Balance Sheets
Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
As of December 31, 2014:
LNG Inventory Derivatives		$	1,071			$	1,000			$	71			$	—		$	—		$	71
Term Gas Supply Derivatives		662				—				662				—			—			662
Term Gas Supply Derivatives		(320		)		—				(320		)		—			—			(320		)
Interest Rate Derivatives - Not Designated		11,158				—				11,158				—			—			11,158
Interest Rate Derivatives - Not Designated		(23,194		)		—				(23,194		)		—			—			(23,194		)
As of December 31, 2013:
LNG Inventory Derivatives		(156		)		(156		)		—				—			—			—
Interest Rate Derivatives - Not Designated		98,123				—				98,123				—			—			98,123
Interest Rate Derivatives - Not Designated		(13,484		)		—				(13,484		)		—			—			(13,484		)

Accrued_Liabilities_Notes

Accrued Liabilities (Notes)	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES
	As of December 31, 2014 and 2013, accrued liabilities consisted of the following (in thousands):
		December 31,
		2014		2013
	Interest expense and related debt fees	$	97,785	$	65,153
	LNG liquefaction costs	15,753		79,422
	Total accrued liabilities	$	113,538	$	144,575

LongTerm_Debt_Notes

Long-Term Debt (Notes)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-term Debt	LONG-TERM DEBT
	As of December 31, 2014 and 2013, our long-term debt consisted of the following (in thousands):
			December 31,
			2014		2013
	Long-term debt
	2021 Senior Notes		$	2,000,000	$	2,000,000
	2022 Senior Notes		1,000,000		1,000,000
	2023 Senior Notes		1,500,000		1,000,000
	2024 Senior Notes		2,000,000		—
	2013 Liquefaction Credit Facilities		—		100,000
	Total long-term, debt		6,500,000		4,100,000
	Long-term debt premium
	2021 Senior Notes		10,177		11,562
	2023 Senior Notes		7,089		—
	Total long-term debt, net		$	6,517,266	$	4,111,562
	For the years ended December 31, 2014, 2013 and 2012, we incurred $397.9 million, $241.3 million and $35.3 million of total interest cost, respectively, of which we capitalized and deferred $374.0 million, $227.9 million and $35.1 million, respectively, of interest cost, including amortization of debt issuance costs, related to the construction of Trains 1 through 4 of the Liquefaction Project.
	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2014 (in thousands):
			Payments Due for the Years Ended December 31,
			Total		2015		2016 to 2017		2018 to 2019		Thereafter
	Debt:
	2021 Senior Notes		$	2,000,000	$	—	$	—	$	—	$	2,000,000
	2022 Senior Notes		1,000,000		—		—		—		1,000,000
	2023 Senior Notes		1,500,000		—		—		—		1,500,000
	2024 Senior Notes		2,000,000		—		—		—		2,000,000
	Total Debt		$	6,500,000	$	—	$	—	$	—	$	6,500,000
	Senior Notes
	In February 2013 and April 2013, we issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Senior Notes. In April 2013 and May 2014, we issued an aggregate principal amount of $1.5 billion, before premium, of the 2023 Senior Notes. Borrowings under the 2021 Senior Notes and 2023 Senior Notes bear interest at a fixed rate of 5.625%. In November 2013, we issued an aggregate principal amount of $1.0 billion of the 2022 Senior Notes. Borrowings under the 2022 Senior Notes bear interest at a fixed rate of 6.25%. In May 2014, we issued an aggregate principal amount of $2.0 billion of the 2024 Senior Notes. Borrowings under the 2024 Senior Notes bear interest at a fixed rate of 5.75%. Interest on the Senior Notes is payable semi-annually in arrears.
	The terms of the Senior Notes are governed by a common indenture (the “Indenture”). The Indenture contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of our restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, consolidate, merge, sell or lease all or substantially all of our assets and enter into certain LNG sales contracts. Subject to permitted liens, the Senior Notes are secured on a pari passu first-priority basis by a security interest in all of our membership interests and substantially all of our assets. We may not make any distributions until, among other requirements, substantial completion of Trains 1 and 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.
	At any time prior to November 1, 2020, with respect to the 2021 Senior Notes; December 15, 2021, with respect to the 2022 Senior Notes; January 15, 2023, with respect to the 2023 Senior Notes; or February 15, 2024, with respect to the 2024 Senior Notes; we may redeem all or part of such series of the Senior Notes at a redemption price equal to the “make-whole” price set forth in the Indenture, plus accrued and unpaid interest, if any, to the date of redemption. We may also at any time on or after November 1, 2020, with respect to the 2021 Senior Notes; December 15, 2021, with respect to the 2022 Senior Notes; January 15, 2023, with respect to the 2023 Senior Notes; or February 15, 2024, with respect to the 2024 Senior Notes, redeem all or part of such series of the Senior Notes at a redemption price equal to 100% of the principal amount of such series of the Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.
	2013 Liquefaction Credit Facilities
	In May 2013, we entered into the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four Trains of the Liquefaction Project. The 2013 Liquefaction Credit Facilities will mature on the earlier of May 28, 2020 or the second anniversary of the completion date of the first four Trains of the Liquefaction Project, as defined in the 2013 Liquefaction Credit Facilities. Borrowings under the 2013 Liquefaction Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. We made an initial $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent, and in May 2014, we repaid our borrowings under the 2013 Liquefaction Credit Facilities upon the issuance of the Additional 2023 Senior Notes and the 2024 Senior Notes. As of December 31, 2014 and 2013, we had $2.7 billion and $4.9 billion, respectively, of available commitments under the 2013 Liquefaction Credit Facilities.
	Borrowings under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at our election, the London Interbank Offered Rate (“LIBOR”) or the base rate, plus the applicable margin. The applicable margins for LIBOR loans range from 2.3% to 3.0% prior to the completion of Train 4 and from 2.3% to 3.25% after such completion, depending on the applicable 2013 Liquefaction Credit Facility. Interest on LIBOR loans is due and payable at the end of each LIBOR period. The 2013 Liquefaction Credit Facilities required us to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144 million and provide for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment due quarterly in arrears. Annual administrative fees must also be paid to the agent and the trustee. The principal of the loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing with the earlier of the last day of the first full calendar quarter after the Train 4 completion date, as defined in the 2013 Liquefaction Credit Facilities, or September 30, 2018. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2013 Liquefaction Credit Facilities.
	Under the terms and conditions of the 2013 Liquefaction Credit Facilities, all cash held by us is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and are classified as restricted on our Balance Sheets.
	The 2013 Liquefaction Credit Facilities contain conditions precedent for any subsequent borrowings, as well as customary affirmative and negative covenants. Our obligations under the 2013 Liquefaction Credit Facilities are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes.
	Under the terms of the 2013 Liquefaction Credit Facilities, we are required to hedge not less than 75% of the variable interest rate exposure of our projected outstanding borrowings, calculated on a weighted average basis in comparison to our anticipated draw of principal. See Note 5—Derivative Instruments.
	In November 2013, in conjunction with our issuance of the 2022 Notes, we terminated approximately $885 million of commitments under the 2013 Liquefaction Credit Facilities. This termination resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Liquefaction Credit Facilities of $43.3 million in November 2013.
	In May 2014, in conjunction with our issuance of the 2024 Senior Notes and the Additional 2023 Senior Notes, we terminated approximately $2.1 billion of commitments under the 2013 Liquefaction Credit Facilities. This termination resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Liquefaction Credit Facilities of $114.3 million in May 2014.
	2012 Liquefaction Credit Facility
	In July 2012, we entered into the 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 and 2 of the Liquefaction Project. Borrowings under the 2012 Liquefaction Credit Facility were based on LIBOR plus 3.50% during construction and LIBOR plus 3.75% during operations. We were also required to pay commitment fees on the undrawn amount. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.
	Under the terms of the 2012 Liquefaction Credit Facility, we were required to hedge not less than 75% of the variable interest rate exposure of our projected outstanding borrowings, calculated on a weighted average basis in comparison to our anticipated draw of principal. See Note 5—Derivative Instruments.
	In conjunction with the issuance of the 2021 Senior Notes in February 2013 and the issuances of $500.0 million of additional 2021 Senior Notes and 2023 Senior Notes in April 2013, approximately $1.4 billion of commitments under the 2012 Liquefaction Credit Facility were terminated. The termination of these commitments in April 2013 and the amendment and restatement of the 2012 Liquefaction Credit Facility with the 2013 Liquefaction Credit Facilities in May 2013 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2012 Liquefaction Credit Facility of $88.3 million during the year ended December 31, 2013.
	Sabine Pass Liquefaction LC Agreement
	In April 2014, we entered into a $325.0 million senior letter of credit and reimbursement agreement (the “Senior LC Agreement”) that we use for the issuance of letters of credit for certain working capital requirements related to the Liquefaction Project. We pay (a) a commitment fee in an amount equal to an annual rate of 0.75% of an amount equal to the unissued portion of letters of credit available pursuant to the Senior LC Agreement and (b) a letter of credit fee equal to an annual rate of 2.5% of the undrawn portion of all letters of credit issued under the Senior LC Agreement. If draws are made upon any letters of credit issued under the Senior LC Agreement, the amount of the draw will be deemed a loan issued to us.  We are required to pay the full amount of this loan on or prior to the business day immediately succeeding the deemed issuance of the loan.  These loans bear interest at a rate of 2.0% plus the base rate as defined in the Senior LC Agreement. As of December 31, 2014, we had issued letters of credit in an aggregate amount of $9.5 million and no draws had been made upon any letters of credit issued under the Senior LC Agreement.
	Fair Value Disclosures
	The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:
			December 31, 2014				December 31, 2013
			Carrying		Estimated		Carrying		Estimated
			Amount		Fair Value		Amount		Fair Value
	2021 Senior Notes, net of premium (1)		$	2,010,177	$	1,985,050	$	2,011,562	$	1,961,273
	2022 Senior Notes (1)		1,000,000		1,020,000		1,000,000		982,500
	2023 Senior Notes, net of premium (1)		1,507,089		1,476,947		1,000,000		935,000
	2024 Senior Notes (1)		2,000,000		1,970,000		—		—
	2013 Liquefaction Credit Facilities (2)		—		—		100,000		100,000
	-1	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.
	-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS
	Services Agreements
	We recorded general and administrative expense—affiliate of $70.6 million, $92.6 million and $34.0 million during the years ended December 31, 2014, 2013 and 2012, respectively, under the services agreements listed below.
	Liquefaction O&M Agreement
	We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments pursuant to which we receive all of the necessary services required to construct, operate and maintain the liquefaction facilities. Before the liquefaction facilities are operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the liquefaction facilities are operational, the services include all necessary services required to operate and maintain the liquefaction facilities. Before the liquefaction facilities are operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the liquefaction facilities are operational, we will pay in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to such Train. Cheniere Investments provides the services required under the Liquefaction O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere.
	Liquefaction MSA
	We have 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 our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the liquefaction facilities. We pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 for services with respect to such Train.
	Terminal Use Agreements
	We have entered into a TUA with Sabine Pass LNG pursuant to which we have reserved approximately 2.0 Bcf/d of regasification capacity. See Note 10—Commitments and Contingencies for additional information regarding this TUA.
	Cheniere Marketing SPA
	Cheniere Marketing has entered into an amended and restated SPA with us (the “Cheniere Marketing SPA”) to purchase, at Cheniere Marketing’s option, LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG.
	LNG Site Sublease Agreement
	In June 2012, we entered into an agreement with Sabine Pass LNG to sublease a portion of its Sabine Pass LNG terminal site for the Liquefaction Project. See Note 9—Leases for additional information regarding this sublease agreement.
	State Tax Sharing Agreement
	In August 2012, we entered into a state tax sharing agreement with Cheniere. See Note 10—Commitments and Contingencies for additional information regarding this agreement.
	Cooperation Agreement
	We have entered into an agreement with Sabine Pass LNG to allow us certain rights to access the property and facilities that are owned by Sabine Pass LNG for the purpose of constructing, modifying and operating our Liquefaction Project. In consideration for access given to us, we have agreed to transfer title to Sabine Pass LNG of certain facilities, equipment and modifications. The term of this agreement is consistent with our TUA described above. As of December 31, 2014, we have conveyed $0.7 million of assets to Sabine Pass LNG under this agreement.

Leases_Notes

Leases (Notes)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Leases	LEASES
	During the years ended December 31, 2014, 2013 and 2012, we recognized rental expense for all operating leases of $0.9 million, $0.9 million and $0.7 million, respectively.
	Future annual minimum lease payments, excluding inflationary adjustments, are as follows (in thousands):
	Year ending December 31,		Lease Payments
	2015		$	908
	2016		874
	2017		770
	2018		770
	2019		770
	Thereafter (1)		53,606
	Total		$	57,698
	-1	Includes certain lease option renewals as they are reasonably assured.
	LNG Site Leases
	In November 2011, we entered into a land lease of 80.7 acres to be used as the laydown area during the construction of the Liquefaction Project. The lease has an initial term of 5 years, with options to renew for five 1-year extensions with similar terms as the initial term.
	In December 2011, we entered into a land lease of 80.6 acres to be used for the site of the Liquefaction Project. The lease has an initial term of 30 years, with options to renew for six 10-year extensions with similar terms as the initial term. The annual lease payment is adjusted for inflation every 5 years based on a consumer price index, as defined in the lease agreement.
	In June 2012, we entered into an agreement with Sabine Pass LNG to sublease a portion of its Sabine Pass LNG terminal site for the Liquefaction Project. The annual sublease payment is $0.5 million. The initial term of the sublease expires on December 31, 2034, with options to renew for five 10-year extensions with similar terms as the initial term. The annual sublease payment is adjusted for inflation every 5 years based on a consumer price index, as defined in the sublease agreement. During the years ended December 31, 2014, 2013 and 2012, we recorded $0.5 million, $0.5 million and $0.3 million of sublease expense as general and administrative expense—affiliate on our Statements of Operations.

Commitments_and_Contingencies_

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES
	Bechtel EPC Contract
	We entered into lump sum turnkey EPC contracts for Trains 1 and 2 (the “EPC Contract (Trains 1 and 2)”) and Trains 3 and 4 (the “EPC Contract (Trains 3 and 4)”) with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) in November 2011 and December 2012, respectively.
	The EPC Contract (Trains 1 and 2) provides that we will pay Bechtel a contract price of $3.9 billion, which is subject to adjustment by change order. We have the right to terminate the EPC Contract (Trains 1 and 2) for our convenience, in which case Bechtel will be paid (i) the portion of the contract price for the work performed, (ii) costs reasonably incurred by Bechtel on account of such termination and demobilization, and (iii) a lump sum of up to $30.0 million depending on the termination date.
	The EPC Contract (Trains 3 and 4) provides for (i) the procurement, engineering, design, installation, training, commissioning and placing into service of Trains 3 and 4 of the Liquefaction Project and related facilities and (ii) certain modifications and improvements to Trains 1 and 2 and the Sabine Pass LNG terminal. The EPC Contract (Trains 3 and 4) provides that we will pay Bechtel a contract price of $3.8 billion, which is subject to adjustment by change order. We have the right to terminate the EPC Contract (Trains 3 and 4) for our convenience, in which case Bechtel will be paid (i) the portion of the contract price for the work performed, (ii) costs reasonably incurred by Bechtel on account of such termination and demobilization, and (iii) a lump sum of up to $30.0 million depending on the termination date.
	LNG Sale and Purchase Agreements
	We have entered into third-party SPAs with four customers which obligate us to purchase natural gas in sufficient quantities, liquefy the natural gas purchased, and deliver 834.0 million MMBtu per year of LNG to the customers’ vessels, subject to completion of construction of each of Trains 1 through 4 of the Liquefaction Project as specified in the customers’ SPAs. In addition, we have entered into third-party SPAs with two customers to purchase natural gas in sufficient quantities, liquefy the natural gas purchased, and deliver 196.0 million MMBtu per year of LNG to the customers’ vessels, subject to completion of regulatory approvals, securing adequate financing, reaching a positive final investment decision to construct the relevant infrastructure, and construction of Train 5 of the Liquefaction Project.
	Terminal Use Agreements
	We have entered into a TUA with Sabine Pass LNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG. We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to Sabine Pass LNG aggregating approximately $250 million per year, continuing until at least 20 years after we deliver our first commercial cargo at our facilities under construction. We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA. In connection with the assignment, we, Cheniere Investments and Sabine Pass LNG also entered into a terminal use rights assignment and agreement (“TURA”) pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to Sabine Pass LNG.  Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. The percentage of the monthly capacity payments payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the monthly capacity payments payable by us will increase by the amount that Cheniere Investments’ percentage decreases. Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA.
	In connection with our TUA, we are required to pay for a portion of the cost (primarily LNG inventory) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. Our portion of the cost (including affiliate) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. During the years ended December 31, 2014, 2013 and 2012, we recorded $26.7 million, $26.6 million and $10.1 million, respectively, as terminal use agreement maintenance expense (including affiliate) on our Statements of Operations related to this obligation.
	In September 2012, we entered into a partial TUA assignment agreement with Total Gas & Power North America, Inc. (“Total”), whereby we will progressively gain access to Total’s capacity and other services provided under Total’s TUA with Sabine Pass LNG. This agreement provides us with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to accommodate the development of Trains 5 and 6, provides increased flexibility in managing LNG cargo loading and unloading activity starting with the commencement of commercial operations of Train 3, and permits us to more flexibly manage our storage with the commencement of Train 1. Notwithstanding any arrangements between Total and us, payments required to be made by Total to Sabine Pass LNG continue to be made by Total to Sabine Pass LNG in accordance with its TUA.
	State Tax Sharing Agreement
	In August 2012, we entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were calculated on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.
	Services Agreements
	We have entered into certain services agreements with affiliates. See Note 8—Related Party Transactions for information regarding such agreements.
	Legal Proceedings
	We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of December 31, 2014, there were no threatened or pending legal matters that would have a material impact on our results of operations, financial position or cash flows.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information (Notes)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION
	The following table provides supplemental disclosure of cash flow information (in thousands):
		Year Ended December 31,
		2014		2013		2012
	Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliates)	$	117,442	$	163,830	$	99,680

Quarterly_Financial_Data_unaud

Quarterly Financial Data (unaudited) (Notes)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Quarterly Financial Data—(in thousands)
		First			Second			Third			Fourth
		Quarter			Quarter			Quarter			Quarter
	Year ended December 31, 2014:
	Revenues	$	—		$	—		$	—		$	—
	Loss from operations	(24,988		)	(38,640		)	(32,365		)	(24,046		)
	Net loss	(59,840		)	(213,477		)	(43,559		)	(59,977		)
	Year ended December 31, 2013:
	Revenues	$	—		$	—		$	—		$	—
	Loss from operations	(15,814		)	(39,756		)	(50,842		)	(29,724		)
	Net loss	(33,861		)	(36,185		)	(73,036		)	(51,408		)

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Presentation, Policy	Basis of Presentation
	Our Financial Statements were prepared in accordance with GAAP. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows.
Use of Estimates, Policy	Use of Estimates
	The preparation of Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
Fair Value, Policy	Fair Value
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.
	In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates.
	Recurring fair-value measurements are performed for commodity derivatives and interest-rate derivatives as disclosed in Note 5—Derivative Instruments. The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 7—Long-Term Debt, are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments. Non-financial assets and liabilities initially measured at fair value include intangible assets and AROs.
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Restricted Cash and Cash Equivalents, Policy	Restricted Cash and Cash Equivalents
	Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets.
	Amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal and will not become available to us as cash and cash equivalents. For these amounts, we have presented increases and decreases as “investments in (uses of) restricted cash and cash equivalents” in our Statements of Cash Flows. These amounts that represent non-cash transactions within our Statements of Cash Flows present the effect of sources and uses of restricted cash and cash equivalents as they relate to the changes to assets and liabilities in our Balance Sheets. Restricted cash and cash equivalents are presented on a gross basis within each of those categories so as to reconcile the change in non-cash activity that occurs on the balance sheet from period to period.
LNG Inventory, Policy	LNG Inventory
	LNG inventory is recorded at cost and is subject to lower of cost or market (“LCM”) adjustments at the end of each period. LNG inventory cost is determined using the average cost method. Terminal use agreement maintenance expense—affiliate represents the amount recorded related to the reimbursement to Sabine Pass LNG of a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal.
Accounting for LNG Activities, Policy	Accounting for LNG Activities
	Generally, we begin capitalizing the costs of a Train once it meets the following criteria: (i) regulatory approval has been received, (ii) financing for the Train is available and (iii) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a Train are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals, and other preliminary investigation and development activities related to the Train.
	Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as intangible LNG assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed.
	We capitalize interest and other related debt costs during the construction period of a Train. Upon commencement of operations, capitalized interest, as a component of the total cost, will be amortized over the estimated useful life of the asset.
Property, Plant and Equipment, Policy	Property, Plant and Equipment
	Property, plant and equipment are recorded at cost. Expenditures for construction activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses.
	Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. In performing this test, an undiscounted cash flow analysis is performed at the lowest level for which identifiable cash flows are independent of cash flows from other assets. If the sum of the undiscounted future net cash flows is less than the net book value of the property, an impairment loss is recognized for the excess, if any, of the property’s net book value over its estimated fair value.  We have recorded no impairments related to property, plant and equipment for 2014, 2013 and 2012.
Derivative Instruments, Policy	Derivative Instruments
	We use derivative instruments to hedge our exposure to cash-flow variability from commodity price and interest rate risk.
	Derivative instruments are recorded at fair value and included in the balance sheet as assets or liabilities depending on the derivative position and the expected timing of settlement. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis.
	Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did not have any derivative instruments designated as cash flow hedges as of December 31, 2014 and 2013.
	From time to time we have elected cash flow hedge accounting for derivatives that we use to hedge the exposure to volatility in floating-rate interest payments. Changes in fair value of derivative instruments designated as cash flow hedges, to the extent the hedge is effective, are recognized in accumulated other comprehensive loss on our Balance Sheets. We reclassify gains and losses on the hedges from accumulated other comprehensive loss into interest expense in our Statements of Operations as the hedged item is recognized. Any change in the fair value resulting from ineffectiveness is recognized immediately as derivative gain (loss) on our Statements of Operations. We use regression analysis to determine whether we expect a derivative to be highly effective as a cash flow hedge prior to electing hedge accounting and also to determine whether all derivatives designated as cash flow hedges have been effective. We perform these effectiveness tests prior to designation for all new hedges and on a quarterly basis for all existing hedges. We calculate the actual amount of ineffectiveness on our cash flow hedges using the “dollar offset” method, which compares changes in the expected cash flows of the hedged transaction to changes in the value of expected cash flows from the hedge. We discontinue hedge accounting when our effectiveness tests indicate that a derivative is no longer highly effective as a hedge; when the derivative expires or is sold, terminated or exercised; when the hedged item matures, is sold or repaid; or when we determine that the occurrence of the hedged forecasted transaction is not probable. When we discontinue hedge accounting but continue to hold the derivative, prospective changes in fair value of the derivative instrument are recorded in income. Once we conclude that the hedged forecasted transaction becomes probable of not occurring, the amount remaining in accumulated other comprehensive loss pertaining to the previously designated derivatives is reclassified out of accumulated other comprehensive loss and into income.
	See Note 5—Derivative Instruments of our Notes to Financial Statements for additional details about our derivative instruments.
Concentration of Credit Risk, Policy	Concentration of Credit Risk
	Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date.
	The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as an other current asset and not netted within the derivative fair value. Our interest rate derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments.
	We have entered into six fixed-price 20-year SPAs with six unaffiliated third parties. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective SPAs.
Long-Term Debt, Policy	Long-Term Debt
	Our debt consists of long-term secured debt securities and credit facilities with banks and other lenders.  Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors.
	Debt is recorded on our balance sheet at par value adjusted for unamortized discount or premium. Discounts, premiums and costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Statements of Operations.
	Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as debt issuance costs on our Balance Sheets and are being amortized to interest expense or property, plant and equipment over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off to loss on early extinguishment of debt.
Asset Retirement Obligations, Policy	Asset Retirement Obligations
	We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our recognition of AROs is described below.
	Currently, the liquefaction facilities under construction at the Sabine Pass LNG terminal adjacent to the existing regasification facilities are our only long-lived asset. Based on the real property lease agreements and sublease agreements at the Sabine Pass LNG terminal, at the expiration of the term of the leases we are required to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease and sublease agreements have terms of up to 90 years including renewal options. We have determined that the cost to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero. Therefore, we have not recorded an ARO associated with the liquefaction facilities at the Sabine Pass LNG terminal.
Income Taxes, Policy	Income Taxes
	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.
	At December 31, 2014, the tax basis of our assets and liabilities was $303.9 million more than the reported amounts of our assets and liabilities.
	Pursuant to the indentures governing our long-term debt, we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the state tax sharing agreement discussed immediately below. The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
	In August 2012, we entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were computed on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):
		December 31,
		2014			2013
	LNG terminal costs
	LNG terminal	$	12,821		$	98
	LNG terminal construction-in-process	6,946,242			4,412,077
	Accumulated depreciation	(260		)	—
	Total LNG terminal costs, net	6,958,803			4,412,175
	Fixed assets
	Vehicles	854			309
	Furniture and fixtures	1,154			10
	Machinery and equipment	339			301
	Other	2,292			125
	Accumulated depreciation	(1,047		)	(340		)
	Total fixed assets, net	3,592			405
	Property, plant and equipment, net	$	6,962,395		$	4,412,580

Derivative_Instruments_Tables

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Assets and Liabilities	The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of December 31, 2014 and 2013, which are classified as prepaid expenses and other, non-current derivative assets and derivative liabilities in our Balance Sheets.
		Fair Value Measurements as of
		31-Dec-14															31-Dec-13
		Quoted Prices in Active Markets				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)				Total			Quoted Prices in Active Markets			Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)		Total
		(Level 1)															(Level 1)
	LNG Inventory Derivatives asset (liability)	$	—			$	1,071			$	—			$	1,071		$	—		$	(156	)		$	—	$	(156	)
	Term Gas Supply Derivatives asset	—				—				342				342			—			—				—		—
	Interest Rate Derivatives asset (liability)	—				(12,036		)		—				(12,036		)	—			84,639				—		84,639
Fair Value Measurements, Sensitivity to Changes in Significant Unobservable Inputs for Level 3	The following table (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs as of December 31, 2014:
			Net Fair Value Asset		Valuation Technique		Significant Unobservable Input		Significant Unobservable Inputs Range
	Term Gas Supply Derivatives		$342		Basis Spread plus Liquid Location		Basis Spread		$ (0.350) - $0.035
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value and location of our commodity derivatives on our Balance Sheets:
					Fair Value Measurements as of
		Balance Sheet Location			December 31, 2014				December 31, 2013
	LNG Inventory Derivatives asset	Prepaid expenses and other			$	1,071			$	156
	Term Gas Supply Derivatives asset	Prepaid expenses and other			76				—
	Term Gas Supply Derivatives asset	Non-current derivative assets			586				—
	Term Gas Supply Derivatives liability	Derivative liabilities			(53		)		—
	Term Gas Supply Derivatives liability	Non-current derivative liabilities			(267		)		—
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our Commodity Derivatives recorded on our Statements of Operations during the years ended December 31, 2014, 2013 and 2012:
			Year Ended December 31,
		Statement of Operation Location	2014				2013				2012
	LNG Inventory Derivatives gain	Derivative gain (loss), net	$	860			$	476			$	—
	Term Gas Supply Derivatives gain (1)	Operating and maintenance expense	342				—				—
	(1)    There were no settlements during the reporting period.
Schedule of Notional Amounts of Outstanding Derivative Positions	At December 31, 2014, we had the following Interest Rate Derivatives outstanding:
			Initial Notional Amount		Maximum Notional Amount		Effective Date		Maturity Date		Weighted Average Fixed Interest Rate Paid		Variable Interest Rate Received
	Interest Rate Derivatives - Not Designated		$20.0 million		$2.5 billion		August 14, 2012		July 31, 2019		1.98%		One-month LIBOR
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following table (in thousands) details the effect of our Interest Rate Derivatives included in Other Comprehensive Income (“OCI”) and AOCI for the years ended December 31, 2014, 2013 and 2012:
			Gain (Loss) in OCI				Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	31-Dec-12
	Interest Rate Derivatives - Designated		$	(21,290	)		$	—			$	—
	Interest Rate Derivatives - De-designated		(5,814		)		—				—
	Interest Rate Derivatives - Settlements		(136		)		—				—
	31-Dec-13
	Interest Rate Derivatives - Designated		21,297				—				5,807
	Interest Rate Derivatives - Settlements		(30		)		—				166
	31-Dec-14
	Interest Rate Derivatives - Designated		—				—				—
	Interest Rate Derivatives - De-designated		—				—				—
	Interest Rate Derivatives - Settlements		—				—				—
Derivative Gross Presentation on Balance Sheets	The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:
			Gross Amounts Recognized				Gross Amounts Offset in the Balance Sheets				Net Amounts Presented in the Balance Sheets				Gross Amounts Not Offset in the Balance Sheets
	Offsetting Derivative Assets (Liabilities)														Derivative Instrument			Cash Collateral Received (Paid)			Net Amount
	As of December 31, 2014:
	LNG Inventory Derivatives		$	1,071			$	1,000			$	71			$	—		$	—		$	71
	Term Gas Supply Derivatives		662				—				662				—			—			662
	Term Gas Supply Derivatives		(320		)		—				(320		)		—			—			(320		)
	Interest Rate Derivatives - Not Designated		11,158				—				11,158				—			—			11,158
	Interest Rate Derivatives - Not Designated		(23,194		)		—				(23,194		)		—			—			(23,194		)
	As of December 31, 2013:
	LNG Inventory Derivatives		(156		)		(156		)		—				—			—			—
	Interest Rate Derivatives - Not Designated		98,123				—				98,123				—			—			98,123
	Interest Rate Derivatives - Not Designated		(13,484		)		—				(13,484		)		—			—			(13,484		)
Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value of our Interest Rate Derivatives:
					Fair Value Measurements as of
			Balance Sheet Location		December 31, 2014				December 31, 2013
	Interest Rate Derivatives - Not Designated		Non-current derivative assets		$	11,158			$	98,123
	Interest Rate Derivatives - Not Designated		Derivative liabilities		(23,194		)		(13,484		)
Interest Rate Contract [Member] | Derivative gain (loss), net [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Statements of Operations during the years ended December 31, 2014, 2013 and 2012:
		Year Ended December 31,
		2014				2013				2012
	Interest Rate Derivatives - Not Designated	$	(119,401	)		$	88,596			$	679

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities [Abstract]
Schedule of Accrued Liabilities	As of December 31, 2014 and 2013, accrued liabilities consisted of the following (in thousands):
		December 31,
		2014		2013
	Interest expense and related debt fees	$	97,785	$	65,153
	LNG liquefaction costs	15,753		79,422
	Total accrued liabilities	$	113,538	$	144,575

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	As of December 31, 2014 and 2013, our long-term debt consisted of the following (in thousands):
			December 31,
			2014		2013
	Long-term debt
	2021 Senior Notes		$	2,000,000	$	2,000,000
	2022 Senior Notes		1,000,000		1,000,000
	2023 Senior Notes		1,500,000		1,000,000
	2024 Senior Notes		2,000,000		—
	2013 Liquefaction Credit Facilities		—		100,000
	Total long-term, debt		6,500,000		4,100,000
	Long-term debt premium
	2021 Senior Notes		10,177		11,562
	2023 Senior Notes		7,089		—
	Total long-term debt, net		$	6,517,266	$	4,111,562
Schedule of Maturities of Long-term Debt	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2014 (in thousands):
			Payments Due for the Years Ended December 31,
			Total		2015		2016 to 2017		2018 to 2019		Thereafter
	Debt:
	2021 Senior Notes		$	2,000,000	$	—	$	—	$	—	$	2,000,000
	2022 Senior Notes		1,000,000		—		—		—		1,000,000
	2023 Senior Notes		1,500,000		—		—		—		1,500,000
	2024 Senior Notes		2,000,000		—		—		—		2,000,000
	Total Debt		$	6,500,000	$	—	$	—	$	—	$	6,500,000
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:
			December 31, 2014				December 31, 2013
			Carrying		Estimated		Carrying		Estimated
			Amount		Fair Value		Amount		Fair Value
	2021 Senior Notes, net of premium (1)		$	2,010,177	$	1,985,050	$	2,011,562	$	1,961,273
	2022 Senior Notes (1)		1,000,000		1,020,000		1,000,000		982,500
	2023 Senior Notes, net of premium (1)		1,507,089		1,476,947		1,000,000		935,000
	2024 Senior Notes (1)		2,000,000		1,970,000		—		—
	2013 Liquefaction Credit Facilities (2)		—		—		100,000		100,000
	-1	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.
	-2	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	Future annual minimum lease payments, excluding inflationary adjustments, are as follows (in thousands):
	Year ending December 31,		Lease Payments
	2015		$	908
	2016		874
	2017		770
	2018		770
	2019		770
	Thereafter (1)		53,606
	Total		$	57,698
	-1	Includes certain lease option renewals as they are reasonably assured.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in thousands):
		Year Ended December 31,
		2014		2013		2012
	Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliates)	$	117,442	$	163,830	$	99,680

Quarterly_Financial_Data_unaud1

Quarterly Financial Data (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Quarterly Financial Data—(in thousands)
		First			Second			Third			Fourth
		Quarter			Quarter			Quarter			Quarter
	Year ended December 31, 2014:
	Revenues	$	—		$	—		$	—		$	—
	Loss from operations	(24,988		)	(38,640		)	(32,365		)	(24,046		)
	Net loss	(59,840		)	(213,477		)	(43,559		)	(59,977		)
	Year ended December 31, 2013:
	Revenues	$	—		$	—		$	—		$	—
	Loss from operations	(15,814		)	(39,756		)	(50,842		)	(29,724		)
	Net loss	(33,861		)	(36,185		)	(73,036		)	(51,408		)

Organization_and_Nature_of_Ope1

Organization and Nature of Operations (Details)	12 Months Ended
	Dec. 31, 2014
Organization and nature of operations [Line Items]
Limited Liability Company Number Of Members	1
Sabine Pass LNG terminal [Member]
Organization and nature of operations [Line Items]
Number Of LNG Storage Tanks	5
Storage Capacity, in Bcfe	16.9
Number Of Docks	2
Volume of Vessel, in cubic meters	266,000
Regasification capacity, in Bcf/d	4
Number of Liquefaction LNG Trains	6
Train nominal capacity, in mtpa	4.5
Cheniere Energy Partners, LP [Member] | Cheniere Energy Partners LP Holdings, LLC [Member]
Organization and nature of operations [Line Items]
Limited Partners ownership percentage	55.90%
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy, Inc. [Member]
Organization and nature of operations [Line Items]
Noncontrolling interest ownership percentage by Parent	80.10%

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	item
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Impairments related to property, plant and equipment	$0	$0	$0
Number of fixed price contracts	6
Sale and Purchase Agreement, Term of Agreement	20 years
Sale and Purchase Agreement, Number of Unaffiliated Counterparties	6
Asset Retirement Obligation	0
Provision for income taxes	0
Entity Not Subject to Income Taxes, Difference in Bases, Amount	303,900,000
Designated as Hedging Instrument [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Derivative instruments designated as cash flow hedges	0	0
Sabine Pass LNG terminal [Member] | Maximum [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Property Lease Term	90 years
Tax Sharing Agreement [Member] | Cheniere Energy, Inc. [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Income Taxes Paid, Net	$0

Restricted_Cash_and_Cash_Equiv1

Restricted Cash and Cash Equivalents (Details) (USD $)	1 Months Ended	12 Months Ended
	Apr. 30, 2013	Dec. 31, 2014	Dec. 31, 2013	Jul. 31, 2012	31-May-13
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents		$155,810,000	$192,144,000
Non-current restricted cash and cash equivalents		457,053,000	867,590,000
Payment of Liabilities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents		155,810,000	192,144,000
Construction Activities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current restricted cash and cash equivalents		457,053,000	867,590,000
2012 Liquefaction Credit Facility [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				3,600,000,000
2013 Liquefaction Credit Facilities [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity					5,900,000,000
2021 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.63%
Debt Instrument, Increase (Decrease), Net	500,000,000
2022 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%
2023 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		1,500,000,000	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.63%
Debt Instrument, Increase (Decrease), Net		500,000,000
2024 Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Debt Instrument, Face Amount		$2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$6,962,395	$4,412,580
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-260	0
Property, plant and equipment, net	6,958,803	4,412,175
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	12,821	98
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,946,242	4,412,077
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	-1,047	-340
Property, plant and equipment, net	3,592	405
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	854	309
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,154	10
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	339	301
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$2,292	$125

Derivative_Instruments_Narrati

Derivative Instruments - Narrative (Details) (USD $)	12 Months Ended		1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	31-May-14	Nov. 30, 2013
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Asset Transfers Into Level 3	$0	$0
Asset Transfers out of Level 3	0	0
LNG Inventory Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	1,071,000	-156,000
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	0	0
LNG Inventory Derivatives [Member] | Other Current Assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	-1,000,000	200,000
Term Gas Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342,000	0
Fair Value Measurements, Valuation Technique	Basis Spread plus Liquid Location
Fair Value Measurements, Significant Unobservable Input	Basis Spread
Derivative, Collateral Deposit (Call), Right to Reclaim Cash	0
Derivative, Notional Amount, in MMBtu	1,249,380,000
Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-12,036,000	84,639,000
Derivative, Gain (Loss) on Derivative, Net			-9,300,000
2013 Liquefaction Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Repayments of Lines of Credit			2,100,000,000	885,000,000
Minimum [Member] | Term Gas Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value Measurements, Significant Unobservable Inputs Range	-0.035
Derivative, Term of Contract	1 year
Maximum [Member] | Term Gas Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value Measurements, Significant Unobservable Inputs Range	$0.04
Derivative, Term of Contract	7 years

Derivative_Instruments_Fair_Va

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$1,071	($156)
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	1,071	-156
LNG Inventory Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342	0
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Term Gas Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342	0
Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-12,036	84,639
Interest Rate Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-12,036	84,639
Interest Rate Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$0	$0

Derivative_Instruments_Fair_Va1

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$1,071	($156)
LNG Inventory Derivatives [Member] | Prepaid Expenses And Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	1,071	156
Term Gas Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	342	0
Term Gas Supply Derivatives [Member] | Prepaid Expenses And Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	76	0
Term Gas Supply Derivatives [Member] | Noncurrent Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	586	0
Term Gas Supply Derivatives [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-53	0
Term Gas Supply Derivatives [Member] | Non-current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	-267	0
Not Designated as Hedging Instrument [Member] | Noncurrent Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Assets, at Fair Value	11,158	98,123
Not Designated as Hedging Instrument [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities, at Fair Value	$23,194	$13,484

Derivative_Instruments_Derivat

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) (USD $)	12 Months Ended						1 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		31-May-14
LNG Inventory Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$860,000		$476,000		$0
Term Gas Supply Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	0		0		0
Term Gas Supply Derivatives [Member] | Operating and maintenance expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	342,000	[1]	0	[1]	0	[1]
Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net							-9,300,000
Interest Rate Contract [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	($119,401,000)		$88,596,000		$679,000
[1]	There were no settlements during the reporting period.

Derivative_Instruments_Schedul

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

Derivative_Instruments_Schedul1

Derivative Instruments - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Details) (Interest Rate Contract [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	$0	($30)	($136)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	166	0
Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0	21,297	-21,290
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	5,807	0
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	0		-5,814
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0		0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	$0		$0

Derivative_Instruments_Derivat1

Derivative Instruments - Derivative Gross Presentation on Balance Sheets (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$1,071
Derivative Liability, Gross Amounts Recognized		-156
Derivative Asset, Gross Amounts Offset in our Balance Sheets	1,000
Derivative Liability, Gross Amounts Offset in our Balance Sheets		-156
Net Amounts Presented in our Balance Sheets	71	0
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument		0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset, Net Amount	71
Derivative Liability, Net Amount		0
Term Gas Supply Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	662
Derivative Asset, Gross Amounts Offset in our Balance Sheets	0
Net Amounts Presented in our Balance Sheets	662
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Asset, Net Amount	662
Price Risk Derivative 2 [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	-320
Derivative Liability, Gross Amounts Offset in our Balance Sheets	0
Net Amounts Presented in our Balance Sheets	-320
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability, Net Amount	-320
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	11,158	98,123
Derivative Asset, Gross Amounts Offset in our Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	11,158	98,123
Derivative Asset, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset, Net Amount	11,158	98,123
Interest Rate Contract 2 [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	-23,194	-13,484
Derivative Liability, Gross Amounts Offset in our Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	-23,194	-13,484
Derivative Liability, Gross Amount Not Offset in our Balance Sheets - Derivative Instrument	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Net Amount	($23,194)	($13,484)

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$97,785	$65,153
LNG liquefaction costs	15,753	79,422
Total accrued liabilities	$113,538	$144,575

LongTerm_Debt_Schedule_of_Long

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Long-term Debt, Gross	$6,500,000,000	$4,100,000,000
Total long-term debt, net	6,517,266,000	4,111,562,000
Interest costs incurred	397,900,000	241,300,000	35,300,000
Interest costs capitalized and deferred	374,000,000	227,900,000	35,100,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,000,000,000	2,000,000,000
Debt Instrument, Unamortized Premium	10,177,000	11,562,000
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,000,000,000	1,000,000,000
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	1,500,000,000	1,000,000,000
Debt Instrument, Unamortized Premium	7,089,000	0
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,000,000,000	0
2013 Liquefaction Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$0	$100,000,000

LongTerm_Debt_Schedule_of_Matu

Long-Term Debt - Schedule of Maturities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Total	$6,500,000	$4,100,000
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	6,500,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Total	2,000,000	2,000,000
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	2,000,000
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Total	1,000,000	1,000,000
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	1,000,000
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Total	1,500,000	1,000,000
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	1,500,000
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Total	2,000,000	0
2015	0
2016 to 2017	0
2018 to 2019	0
Thereafter	$2,000,000

LongTerm_Debt_Senior_Notes_Det

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

LongTerm_Debt_2013_Liquefactio

Long-Term Debt - 2013 Liquefaction Credit Facilities (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	31-May-14	Nov. 30, 2013	Jun. 30, 2013	31-May-13
Line of Credit Facility [Line Items]
Loss on extinguishment of debt	$114,335,000	$131,576,000	$0
2013 Liquefaction Credit Facilities [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity							5,900,000,000
Proceeds from (Repayments of) Lines of Credit						100,000,000
Line of Credit Facility, Remaining Borrowing Capacity	2,700,000,000	4,900,000,000
Debt Instrument, Description of Variable Rate Basis	LIBOR
Debt Instrument, Fee Amount							144,000,000
Line of Credit Facility, Commitment Fee Percentage	40.00%
Line of Credit Facility, Amortization Period	18 years
Line of Credit Facility, Increase (Decrease)				-2,100,000,000	-885,000,000
Loss on extinguishment of debt				$114,300,000	$43,300,000
2013 Liquefaction Credit Facilities [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives	75.00%
2013 Liquefaction Credit Facilities [Member] | Minimum [Member] | Operations [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
2013 Liquefaction Credit Facilities [Member] | Minimum [Member] | Construction [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
2013 Liquefaction Credit Facilities [Member] | Maximum [Member] | Operations [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.25%
2013 Liquefaction Credit Facilities [Member] | Maximum [Member] | Construction [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.00%

LongTerm_Debt_2012_Liquefactio

Long-Term Debt - 2012 Liquefaction Credit Facility (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	31-May-13	Apr. 30, 2013
Line of Credit Facility [Line Items]
Loss on early extinguishment of debt	$114,335,000	$131,576,000	$0
2012 Liquefaction Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR
Proceeds from (Repayments of) Lines of Credit				-100,000,000
Line of Credit Facility, Increase (Decrease)					-1,400,000,000
Loss on early extinguishment of debt		88,300,000
2012 Liquefaction Credit Facility [Member] | Construction [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.50%
2012 Liquefaction Credit Facility [Member] | Operations [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.75%
2012 Liquefaction Credit Facility [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives	75.00%
2021 Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Increase (Decrease), Net					$500,000,000

LongTerm_Debt_Liquefaction_LC_

Long-Term Debt - Liquefaction LC Agreement (Details) (Liquefaction LC Agreement [Member], USD $)	12 Months Ended
	Dec. 31, 2014
Line of Credit Facility [Line Items]
Letter of Credit and Reimbursement Agreement	$325,000,000
Letter of Credit, Interest Rate	2.00%
Letters of Credit Outstanding, Amount	9,500,000
Letters of Credit, Drawn Amount	$0
Unissued Portion [Member]
Line of Credit Facility [Line Items]
Letter of Credit, Commitment Fee Percentage	0.75%
Portion issued and not drawn [Member]
Line of Credit Facility [Line Items]
Letter of Credit, Commitment Fee Percentage	2.50%

LongTerm_Debt_Schedule_of_Carr

Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	$6,517,266		$4,111,562
2021 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	2,010,177		2,011,562
2021 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,985,050	[1]	1,961,273	[1]
2022 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	1,000,000		1,000,000
2022 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,020,000	[1]	982,500	[1]
2023 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	1,507,089		1,000,000
2023 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,476,947	[1]	935,000	[1]
2024 Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	2,000,000		0
2024 Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,970,000	[1]	0	[1]
2013 Liquefaction Credit Facilities [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt	0		100,000
2013 Liquefaction Credit Facilities [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	$0	[2]	$100,000	[2]
[1]	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on December 31, 2014 and 2013, as applicable.
[2]	The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and we have the ability to call this debt at any time without penalty.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
General and administrative expense—affiliate	$71,065,000	$93,064,000	$33,951,000
Service Agreements [Member]
Related Party Transaction [Line Items]
General and administrative expense—affiliate	70,600,000	92,600,000	34,000,000
Cheniere Energy Investments, LLC [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	0.60%
Related Party Transaction, Committed Monthly Fee	83,333
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member]
Related Party Transaction [Line Items]
Regasification capacity, in Bcf/d	2
Cheniere Marketing, LLC [Member] | LNG Sale and Purchase Agreement [Member]
Related Party Transaction [Line Items]
Incremental LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
Incremental LNG Volume, Purchase Price Per MMBtu	3
Cheniere LNG Terminals, LLC [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	2.40%
Related Party Transaction, Committed Monthly Fee	541,667
Sabine Pass Liquefaction [Member]
Related Party Transaction [Line Items]
Property, Plant and Equipment, Transfers and Changes	$700,000

Leases_Narrative_Details

Leases - Narrative (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Leased Assets [Line Items]
Operating Leases, Rent Expense	$0.90	$0.90	$0.70
Sabine Pass LNG, LP [Member] | LNG Site Sublease Agreement [Member]
Operating Leased Assets [Line Items]
Number Of Available Lease Extensions	5
Lessee Leasing Arrangements, Operating Leases, Renewal Term	10 years
Review Period for Inflation Adjustment	5 years
Annual Lease Payment	0.5
Operating Leases, Rent Expense, Net	$0.50	$0.50	$0.30
Land [Member]
Operating Leased Assets [Line Items]
Acreage under lease	80.7
Property Lease Term	5 years
Number Of Available Lease Extensions	5
Lessee Leasing Arrangements, Operating Leases, Renewal Term	1 year
Land2 [Member]
Operating Leased Assets [Line Items]
Acreage under lease	80.6
Property Lease Term	30 years
Number Of Available Lease Extensions	6
Lessee Leasing Arrangements, Operating Leases, Renewal Term	10 years
Review Period for Inflation Adjustment	5 years

Leases_Schedule_of_Future_Mini

Leases - Schedule of Future Minimum Rental Payments (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Leases [Abstract]
2015	$908
2016	874
2017	770
2018	770
2019	770
Thereafter	53,606	[1]
Total	$57,698
[1]	(1)Includes certain lease option renewals as they are reasonably assured.

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	item
Commitments and Contingencies [Line Items]
Terminal Use Agreement Maintenance Expense Including Affiliate	$26,700,000	$26,600,000	$10,100,000
Loss Contingency, Pending Claims, Number	0
Bechtel EPC Contract - Train One And Two [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Amount	3,900,000,000
Bechtel EPC Contract - Train Three And Four [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Amount	3,800,000,000
Maximum [Member] | Bechtel EPC Contract - Train One And Two [Member]
Commitments and Contingencies [Line Items]
Contract Termination Convenience Penalty	30,000,000
Maximum [Member] | Bechtel EPC Contract - Train Three And Four [Member]
Commitments and Contingencies [Line Items]
Contract Termination Convenience Penalty	30,000,000
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member]
Commitments and Contingencies [Line Items]
Regasification capacity, in Bcf/d	2
Related Party Transaction, Committed Annual Fee	250,000,000
Related Party Agreement Term	20 years
Portion of storage capacity reserved	41.00%
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	100.00%
Sabine Pass LNG, LP [Member] | LNG Terminal Capacity Agreements [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	0.00%
Cheniere Energy, Inc. [Member] | Tax Sharing Agreement [Member]
Commitments and Contingencies [Line Items]
Income Taxes Paid, Net	$0
Fixed Price Contract Trains 1 Through 4 [Member]
Commitments and Contingencies [Line Items]
Contract volumes, in MMBtu per year	834,000,000
Fixed Price Contract Train 5 [Member]
Commitments and Contingencies [Line Items]
Contract volumes, in MMBtu per year	196,000,000

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Information [Abstract]
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliates)	$117,442	$163,830	$99,680

Quarterly_Financial_Data_unaud2

Quarterly Financial Data (unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
Revenues	$0	$0	$0	$0	$0	$0	$0	$0	$0	$0	$0
Loss from operations	-24,046	-32,365	-38,640	-24,988	-29,724	-50,842	-39,756	-15,814	-120,039	-136,136	-85,783
Net loss	($59,977)	($43,559)	($213,477)	($59,840)	($51,408)	($73,036)	($36,185)	($33,861)	($376,853)	($194,490)	($85,157)