Sabine Pass Liquefaction S-4 25 Nov 15 Registration of securities issued in business combination transactions Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Central Index Key	1,499,200
Entity Filer Category	Non-accelerated Filer
Document Type	S4
Document Period End Date	Sep. 30, 2015
Amendment Flag	false

Balance Sheets

Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets
Cash and cash equivalents	$ 0	$ 0	$ 0
Restricted cash	327,150	155,810	192,144
Accounts receivable—affiliate	1,678	2,750	1,167
Advances to affiliate	36,623	23,969	9,430
Other current assets	7,953	3,541	4,390
Other current assets—affiliate	2,848	153	121
Total current assets	376,252	186,223	207,252
Non-current restricted cash	0	457,053	867,590
Property, plant and equipment, net	9,205,564	6,962,395	4,412,580
Debt issuance costs, net	297,374	228,913	296,040
Non-current derivative assets	30,657	11,744	98,123
Other non-current assets	162,772	99,417	60,387
Total assets	10,072,619	7,945,745	5,941,972
Current liabilities
Accounts payable	4,978	5,974	8,067
Accrued liabilities	290,823	113,538	144,575
Due to affiliates	24,591	13,051	26,019
Derivative liabilities	7,388	23,247	13,484
Total current liabilities	327,780	155,810	192,145
Long-term debt, net	8,765,660	6,517,266	4,111,562
Non-current derivative liabilities	8,832	268	$ 0
Other non-current liabilities—affiliate	3,928	$ 0
Commitments and Contingencies
Member’s equity	966,419	$ 1,272,401	$ 1,638,265
Total liabilities and member's equity	$ 10,072,619	$ 7,945,745	$ 5,941,972

Statements of Operations

Statements of Operations - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement [Abstract]
Revenues	$ 0	$ 0	$ 0	$ 0	$ 0
Expenses
Operating and maintenance expense (income)	(27,521)	4,836	6,071	0	0
Operating and maintenance expense—affiliate	456	34	95	0	0
Terminal use agreement maintenance expense (income)	16,684	24,497	25,677	26,228	10,058
Terminal use agreement maintenance expense—affiliate	308	506	387	394	0
Depreciation expense	1,279	671	967	213	119
Development expense	2,631	8,671	9,319	11,540	37,341
Development expense—affiliate	562	723	1,153	1,392	2,955
General and administrative expense	4,027	3,859	5,305	3,305	1,359
General and administrative expense—affiliate	58,304	52,644	71,065	93,064	33,951
Total expenses (income)	56,730	96,441	120,039	136,136	85,783
Income (loss) from operations	(56,730)	(96,441)	(120,039)	(136,136)	(85,783)
Other income (expense)
Interest expense, net of capitalized interest	(31,261)	(16,773)	(23,909)	(10,796)	(139)
Loss on early extinguishment of debt	(96,273)	(114,335)	(114,335)	(131,576)	0
Derivative gain (loss), net	(46,541)	(89,222)	(118,541)	83,266	679
Other income (expense)	320	(105)	(29)	752	86
Total other expense	(173,755)	(220,435)	(256,814)	(58,354)	626
Net loss	$ (230,485)	$ (316,876)	$ (376,853)	$ (194,490)	$ (85,157)

Statements of Comprehensive Los

Statements of Comprehensive Loss - USD ($) $ in Thousands	12 Months Ended
	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)

Statement of Member's Equity (D

Statement of Member's Equity (Deficit) - USD ($) $ in Thousands	Total	Sabine Pass LNG-LP, LLC [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
Members' equity, beginning of period at Dec. 31, 2011	$ (46,380)	$ (46,380)	$ 0
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	1,623,849	1,623,849	0
Non-Cash Equity Contribution from Parent	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]
Capital 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]
Capital contributions from Cheniere Partners	11,734	11,734	0
Non-cash distributions to affiliates	(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
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	15,297	15,297
Non-cash distributions to affiliates	(90,794)	(90,794)
Net loss	(230,485)	(230,485)
Member's equity, end of period at Sep. 30, 2015	$ 966,419	$ 966,419

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net loss	$ (230,485)	$ (316,876)	$ (376,853)	$ (194,490)	$ (85,157)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities
Non-cash terminal use agreement maintenance expense	16,610	23,505	24,461	26,731	9,612
Depreciation expense	1,279	671	967	2,917	119
Amortization of debt issuance costs and premium	1,736	0
Loss on extinguishment of debt	96,273	114,335	114,335	131,576	0
Total losses on derivatives, net	13,136	89,670	118,199	(84,299)	(679)
Net cash used for settlement of derivative instruments	(40,990)	(20,245)	(22,093)	632	0
Changes in restricted cash for certain operating activities	230,187	119,196	175,853	161,065	80,764
Changes in operating assets and liabilities
Advances to affiliate	(12,654)	1,612	(14,539)	(5,017)	(4,414)
LNG inventory	1,952	(24,499)	(22,963)	0	0
Accounts payable and accrued liabilities			9,234	(167)	(1,781)
Accounts payable	(5,621)	5,033
Accrued liabilities	(38,294)	1,018
Due to affiliates	(10,029)	9,639	(2,373)	1,665	11,545
Other, net	(3,825)	(3,188)	(2,644)	(39,446)	(10,009)
Other—affiliate	(19,275)	129	(1,584)	(1,167)	0
Net cash provided by (used in) operating activities	0	0	0	0	0
Cash flows from investing activities
Property, plant and equipment, net	(2,094,567)	(1,888,589)	(2,548,855)	(3,082,195)	(1,113,999)
Use of restricted cash for the acquisition of property, plant and equipment	2,144,821	1,900,776	2,587,565	3,092,025	1,114,742
Other	(50,254)	(12,187)	(38,710)	(9,830)	(743)
Net cash provided by (used in) investing activities	0	0	0	0	0
Cash flows from financing activities
Proceeds from issuances of long-term debt	2,250,000	2,584,500	2,584,500	4,112,500	100,000
Repayments of long-term debt	0	(177,000)	(177,000)	(100,000)	0
Debt issuance and deferred financing costs	(176,002)	(94,290)	(102,687)	(309,404)	(212,412)
Investment in restricted cash	(2,089,295)	(2,323,620)	(2,316,547)	(4,041,372)	(1,466,958)
Capital contributions from Cheniere Partners	15,297	10,410	11,734	338,276	1,623,849
Advances—affiliate			0	0	(44,479)
Net cash provided by (used in) financing activities	0	0	0	0	0
Net increase (decrease) in cash and cash equivalents	0	0	0	0	0
Cash and cash equivalents—beginning of period	0	0	0	0	0
Cash and cash equivalents—end of period	$ 0	$ 0	$ 0	$ 0	$ 0

Organization and Nature of Oper

Organization and Nature of Operations	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.

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	BASIS OF PRESENTATION The accompanying unaudited Financial Statements of SPL have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows. Results of operations for the nine months ended September 30, 2015 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2015 . We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. For further information, refer to the Financial Statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2014 . In June 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on development stage entities. The amendment removed all incremental financial reporting requirements from GAAP for development stage entities. This guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. We adopted this guidance in the quarterly period ended June 30, 2014. Prior to our adoption of this guidance, we were a development stage entity because we devote substantially all of our efforts to establishing a new natural gas liquefaction business and for which planned principal operations have not commenced. The adoption of this guidance did not have a material impact on our financial position, results of operations or cash flows other than the removal of inception-to-date information about statement of operations line items, cash flows and equity transactions.

Summary of Significant Accounti

Summary of Significant Accounting Policies	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 no t 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

Restricted Cash	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Cash and Cash Equivalents [Abstract]
Restricted Cash	RESTRICTED CASH Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. During 2013, we entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 Credit Facilities”) . In June 2015, we entered into four credit facilities aggregating $4.6 billion (collectively, the “2015 Credit Facilities”) , which replaced the 2013 Credit Facilities . Under the terms and conditions of the 2015 Credit Facilities (and previously the 2013 Credit Facilities ), we are required to deposit all cash received into reserve accounts controlled by a collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to our natural gas liquefaction facilities that are being developed and constructed in Cameron Parish, Louisiana (the “Liquefaction Project”) ; therefore, these amounts are shown as restricted cash on our Balance Sheets. During 2013, we issued an aggregate principal amount of $2.0 billion , before premium, of 5.625% Senior Secured Notes due 2021 (the “2021 Senior Notes”) , $1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 Senior Notes”) and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the “Initial 2023 Senior Notes”) . During 2014, we issued an aggregate principal amount of $2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 Senior Notes”) and additional 5.625% Senior Secured Notes due 2023 in an aggregate principal amount of $0.5 billion , before premium (the “Additional 2023 Senior Notes” and collectively with the Initial 2023 Senior Notes, the “2023 Senior Notes”) . In March 2015, we issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 Senior Notes” and collectively with the 2021 Senior Notes, the 2022 Senior Notes, the 2023 Senior Notes and the 2024 Senior Notes, the “Senior Notes”) . The use of cash proceeds from the Senior Notes is restricted to the payment of liabilities related to the Liquefaction Project; therefore, these amounts are shown as restricted cash on our Balance Sheets. See Note 6—Long-Term Debt for additional details about our long-term debt. As of September 30, 2015 and December 31, 2014 , we classified $327.2 million and $155.8 million , respectively, as current restricted cash for the payment of current liabilities, including interest payments, related to the Liquefaction Project and zero and $457.1 million , respectively, as non-current restricted cash for future Liquefaction Project construction costs.	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

Property, Plant and Equipment	9 Months Ended	12 Months Ended
	Sep. 30, 2015	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): September 30, December 31, 2015 2014 LNG terminal costs LNG terminal $ 13,171 $ 12,821 LNG terminal construction-in-process 9,187,749 6,946,242 Accumulated depreciation (540 ) (260 ) Total LNG terminal costs, net 9,200,380 6,958,803 Fixed assets Furniture and fixtures 1,154 1,154 Vehicles 1,379 854 Machinery and equipment 339 339 Other 4,358 2,292 Accumulated depreciation (2,046 ) (1,047 ) Total fixed assets, net 5,184 3,592 Property, plant and equipment, net $ 9,205,564 $ 6,962,395	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

Derivative Instruments	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into the following derivative instruments that are reported at fair value: • commodity derivatives to hedge the exposure to price risk attributable to future sales of our LNG inventory (“Natural Gas Derivatives”) ; • commodity derivatives consisting of natural gas purchase agreements and associated economic hedges to secure natural gas feedstock for the Liquefaction Project (“Liquefaction Supply Derivatives”) ; and • interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 Credit Facilities (and previously the 2013 Credit Facilities ) (“Interest Rate Derivatives”) . None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Operations . The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of September 30, 2015 December 31, 2014 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Natural Gas Derivatives asset $ — $ 423 $ — $ 423 $ — $ 1,071 $ — $ 1,071 Liquefaction Supply Derivatives asset — — 32,546 32,546 — — 342 342 Interest Rate Derivatives liability — (15,738 ) — (15,738 ) — (12,036 ) — (12,036 ) The estimated fair values of our Natural Gas 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 substantially all of our Liquefaction 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 Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of our Liquefaction 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 Liquefaction Supply Derivatives contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, the 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 September 30, 2015 and December 31, 2014 , some of our Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. In the absence of infrastructure to accommodate marketable physical gas flow, our internal fair value models are based on a market price that equates to our own contractual pricing due to: (1) the inactive and unobservable market and (2) 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 our Liquefaction 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. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas purchase agreements as of the reporting date. There were no transfers into or out of Level 3 Liquefaction Supply Derivatives for the nine months ended September 30, 2015 and 2014. As all of our physical Liquefaction 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 includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2015 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Liquefaction Supply Derivatives $32,546 Income Approach Basis Spread $ (0.350) - $0.050 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. 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 when our derivative instruments are in an asset position. Commodity Derivatives We recognize all commodity derivative instruments, including our Natural Gas Derivatives and our Liquefaction Supply Derivatives (collectively, “Commodity Derivatives”) , as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Commodity Derivatives are reported in earnings. The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets: September 30, 2015 December 31, 2014 Natural Gas Derivatives (1) Liquefaction Supply Derivatives Total Natural Gas Derivatives (1) Liquefaction Supply Derivatives Total Balance Sheet Location Other current assets $ 423 $ 2,371 $ 2,794 $ 1,071 $ 76 $ 1,147 Non-current derivative assets — 30,657 30,657 — 586 586 Total derivative assets 423 33,028 33,451 1,071 662 1,733 Derivative liabilities — (349 ) (349 ) — (53 ) (53 ) Non-current derivative liabilities — (133 ) (133 ) — (267 ) (267 ) Total derivative liabilities — (482 ) (482 ) — (320 ) (320 ) Derivative asset, net $ 423 $ 32,546 $ 32,969 $ 1,071 $ 342 $ 1,413 (1) Does not include collateral calls of $0.3 million and $1.0 million for such contracts, which are included in other current assets in our Balance Sheets as of September 30, 2015 and December 31, 2014 , respectively. The following table (in thousands) shows the changes in the fair value and settlements and location of our Commodity Derivatives recorded in operating and maintenance expense (income) on our Statements of Operations during the nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, 2015 2014 Natural Gas Derivatives gain (loss) $ 1,221 $ (448 ) Liquefaction Supply Derivatives gain (1) 32,184 — (1) There were no physical settlements during the reporting period. Natural Gas Derivatives Our Natural Gas 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 Natural Gas Derivatives activities. Liquefaction Supply Derivatives We have entered into index-based physical natural gas supply contracts and associated economic hedges to secure natural gas feedstock for the Liquefaction Project . The terms of the physical 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 Train s of the Liquefaction Project . We recognize our Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Liquefaction Supply Derivatives are reported in earnings. As of September 30, 2015 , we have secured up to approximately 2,156.6 million MMBtu of natural gas feedstock through long-term natural gas purchase agreements, of which the forward notional natural gas buy position of our Liquefaction Supply Derivatives was approximately 1,244.1 million MMBtu , which were recorded as derivatives due to minimum purchase requirements. Interest Rate Derivatives We have entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2015 Credit Facilities. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 Credit Facilities. In March 2015, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the 2013 Credit Facilities , as discussed in Note 6—Long-Term Debt . 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 early termination of approximately $2.1 billion of commitments under the 2013 Credit Facilities . At September 30, 2015 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $20.0 million $628.8 million August 14, 2012 July 31, 2019 1.98% One-month LIBOR The following table (in thousands) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location September 30, 2015 December 31, 2014 Interest Rate Derivatives Derivative liabilities $ (7,039 ) $ (23,194 ) Interest Rate Derivatives Non-current derivative assets (Non-current derivative liabilities) (8,699 ) 11,158 The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Statements of Operations during the nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, 2015 2014 Interest Rate Derivatives gain (loss) $ (46,541 ) $ (89,222 ) Balance Sheet Presentation Our Commodity Derivatives and Interest Rate Derivatives are presented on a net basis on our Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of September 30, 2015 Natural Gas Derivatives $ 460 $ (37 ) $ 423 Liquefaction Supply Derivatives 33,028 — 33,028 Liquefaction Supply Derivatives (482 ) — (482 ) Interest Rate Derivatives (15,738 ) — (15,738 ) As of December 31, 2014 Natural Gas Derivatives 1,079 (8 ) 1,071 Liquefaction Supply Derivatives 662 — 662 Liquefaction Supply Derivatives (320 ) — (320 ) Interest Rate Derivatives 11,158 — 11,158 Interest Rate Derivatives (23,194 ) — (23,194 )	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 December 31, 2014 December 31, 2013 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total 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 December 31, 2012 Interest Rate Derivatives - Designated $ (21,290 ) $ — $ — Interest Rate Derivatives - De-designated (5,814 ) — — Interest Rate Derivatives - Settlements (136 ) — — December 31, 2013 Interest Rate Derivatives - Designated 21,297 — 5,807 Interest Rate Derivatives - Settlements (30 ) — 166 December 31, 2014 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

Accrued Liabilities	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Accrued Liabilities [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of September 30, 2015 and December 31, 2014 , accrued liabilities consisted of the following (in thousands): September 30, December 31, 2015 2014 Interest expense and related debt fees $ 113,267 $ 97,785 Liquefaction Project costs 177,556 15,753 Total accrued liabilities $ 290,823 $ 113,538	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

Long-Term Debt

Long-Term Debt	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-Term Debt	LONG-TERM DEBT As of September 30, 2015 and December 31, 2014 , our long-term debt consisted of the following (in thousands): Interest September 30, December 31, Rate 2015 2014 Long-term debt 2021 Senior Notes 5.625% $ 2,000,000 $ 2,000,000 2022 Senior Notes 6.250% 1,000,000 1,000,000 2023 Senior Notes 5.625% 1,500,000 1,500,000 2024 Senior Notes 5.750% 2,000,000 2,000,000 2025 Senior Notes 5.625% 2,000,000 — 2015 Credit Facilities (1) (2) 250,000 — Working Capital Facility (3) (4) — — Total long-term debt 8,750,000 6,500,000 Long-term debt premium 2021 Senior Notes 9,090 10,177 2023 Senior Notes 6,570 7,089 Total long-term debt, net $ 8,765,660 $ 6,517,266 (1) Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the Liquefaction Project. (2) Variable interest rate, at our election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75% , depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75% . Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter. (3) Matures on December 31, 2020, with various terms for underlying loans as further described below under Working Capital Facility . As of September 30, 2015 and December 31, 2014 , no loans were outstanding under the Working Capital Facility or the LC Agreement it replaced. (4) Variable interest rates, based on LIBOR or the base rate, as further described below under Working Capital Facility . For the nine months ended September 30, 2015 and 2014 , we incurred $388.0 million and $288.3 million of total interest cost, respectively, of which we capitalized and deferred $356.7 million and $271.5 million , respectively, including amortization of debt issuance costs, primarily related to the construction of the Liquefaction Project. Senior Notes In March 2015, we issued an aggregate principal amount of $2.0 billion of the 2025 Senior Notes , for which borrowings accrue interest at a fixed rate of 5.625% . The terms of the 2025 Senior Notes are governed by the same common indenture with the other Senior Notes . In connection with the closing of the sale of the 2025 Senior Notes , we entered into a Registration Rights Agreement dated March 3, 2015 (the “2025 Registration Rights Agreement”) . Under the terms of the 2025 Registration Rights Agreement , we have agreed, and any future guarantors of the 2025 Senior Notes will agree, to use commercially reasonable efforts to file with the Securities and Exchange Commission (“SEC”) and cause to become effective a registration statement within 360 days after March 3, 2015 with respect to an offer to exchange any and all of the 2025 Senior Notes for a like aggregate principal amount of our debt securities with terms identical in all material respects to the respective 2025 Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), and that are registered under the Securities Act of 1933, as amended. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 2025 Senior Notes . We will be obligated to pay additional interest if we fail to comply with our obligation to register the 2025 Senior Notes within the specified time period. 2015 Credit Facilities In June 2015, we entered into the 2015 Credit Facilities with commitments aggregating $4.6 billion . The 2015 Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the Liquefaction Project. Borrowings under the 2015 Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015 , we had $4.3 billion of available commitments and $250.0 million of outstanding borrowings under the 2015 Credit Facilities . We incurred $88.2 million of debt issuance costs in connection with the 2015 Credit Facilities . In addition to interest, we are required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 Credit Facilities . The 2015 Credit Facilities also require us to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment, or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 Credit Facility. The principal of the loans made under the 2015 Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the Liquefaction Project . Scheduled repayments are based upon an 18 -year amortization profile, with the remaining balance due upon the maturity of the 2015 Credit Facilities . The 2015 Credit Facilities contain conditions precedent for borrowings, as well as customary affirmative and negative covenants. Our obligations under the 2015 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 and the Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “Working Capital Facility”) described below. Under the terms of the 2015 Credit Facilities , we are required to hedge not less than 65% 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. 2013 Credit Facilities In May 2013, we entered into the 2013 Credit Facilities to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 4 of the Liquefaction Project. As of December 31, 2014, we had no outstanding borrowings under the 2013 Credit Facilities . In June 2015, the 2013 Credit Facilities were replaced with the 2015 Credit Facilities . In March 2015, in conjunction with our issuance of the 2025 Senior Notes , we terminated approximately $1.8 billion of commitments under the 2013 Credit Facilities . This termination and the replacement of the 2013 Credit Facilities with the 2015 Credit Facilities in June 2015 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Credit Facilities of $96.3 million for the nine months ended September 30, 2015 . Working Capital Facility In September 2015, we entered into a $1.2 billion Working Capital Facility , which replaced the $325.0 million Senior Letter of Credit and Reimbursement Agreement that was entered into in April 2014 (the “LC Agreement”) . The Working Capital Facility is intended to be used for loans (“Working Capital Loans”) , the issuance of letters of credit (“Letters of Credit”) , as well as for swing line loans (“Swing Line Loans”) , primarily for certain working capital requirements related to developing and placing into operation the Liquefaction Project . We may, from time to time, request increases in the commitments under the Working Capital Facility of up to $760 million and, upon the completion of the debt financing of Train 6 of the Liquefaction Project , request an incremental increase in commitments of up to an additional $390 million . As of September 30, 2015 , we had $1.1 billion of available commitments, $127.6 million aggregate amount of issued Letters of Credit and no Working Capital Loans , Swing Line Loans or loans deemed made in connection with a draw upon a Letter of Credit (“LC Loans” and collectively with Working Capital Loans and Swing Line Loans, the “Working Capital Facility Loans”) outstanding under the Working Capital Facility . 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 LC Agreement . Working Capital Facility Loans accrue interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the senior facility agent’s published prime rate, the federal funds effective rate, as published by the Federal Reserve Bank of New York, plus 0.50% and one month LIBOR plus 0.50% ), plus the applicable margin. The applicable margin for LIBOR Working Capital Facility Loans is 1.75% per annum, and the applicable margin for base rate Working Capital Facility Loans is 0.75% per annum. Interest on Swing Line Loans and LC Loans is due and payable on the date the loan becomes due. Interest on LIBOR Working Capital Loans is due and payable at the end of each applicable LIBOR period, and interest on base rate Working Capital Loans is due and payable at the end of each fiscal quarter. However, if such base rate Working Capital Loan is converted into a LIBOR Working Capital Loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date. We incurred $27.5 million of debt issuance costs in connection with the Working Capital Facility . We pay (1) a commitment fee on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans in an amount equal to an annual rate of 0.70% and (2) a Letter of Credit fee equal to an annual rate of 1.75% of the undrawn portion of all Letters of Credit issued under the Working Capital Facility. If draws are made upon a Letter of Credit issued under the Working Capital Facility and we do not elect for such draw (an “LC Draw”) to be deemed an LC Loan, we are required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw . An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of September 30, 2015 , no LC Draw s had been made upon any Letters of Credit issued under the Working Capital Facility . The Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year . Swing Line Loans terminate upon the earliest of (1) the maturity date or earlier termination of the Working Capital Facility , (2) the date 15 days after such Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. We are required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year. The Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. Our obligations under the Working Capital Facility 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 and 2015 Credit Facilities . Fair Value Disclosures The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt: September 30, 2015 December 31, 2014 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value 2021 Senior Notes, net of premium (1) $ 2,009,090 $ 1,853,386 $ 2,010,177 $ 1,985,050 2022 Senior Notes (1) 1,000,000 930,000 1,000,000 1,020,000 2023 Senior Notes, net of premium (1) 1,506,570 1,344,614 1,507,089 1,476,947 2024 Senior Notes (1) 2,000,000 1,765,000 2,000,000 1,970,000 2025 Senior Notes (1) 2,000,000 1,755,000 — — 2015 Credit Facilities (2) 250,000 250,000 — — Working Capital Facility (2) — — — — (1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014 , as applicable. (2) The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.	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 Amount Estimated Fair Value Carrying Amount Estimated 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

Related Party Transactions	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS LNG Terminal-Related Agreements Terminal Use Agreements We have entered into a TUA with SPLNG 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 SPLNG 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 SPLNG also entered into a terminal use rights assignment and agreement (the “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 SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. The percentage of the monthly capacity payments payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the monthly capacity payments payable by us will increase by the amount that Cheniere Investments’ percentage decreases. Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA . In connection with our TUA , we are required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. Terminal use agreement maintenance expense—affiliate represents the amount recorded related to the reimbursement to SPLNG of a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal. Our portion of the cost (including affiliate) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. We recorded terminal use agreement maintenance expense (including affiliate) related to this obligation of $17.0 million and $25.0 million during the nine months ended September 30, 2015 and 2014 , respectively. Cheniere Marketing SPA Cheniere Marketing has entered into an amended and restated SPA with us to purchase, at Cheniere Marketing’s option, LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG. Commissioning Agreement In May 2015, we entered into an agreement with Cheniere Marketing that obligates Cheniere Marketing, in certain circumstances, to buy LNG cargoes produced during the periods while Bechtel Oil, Gas and Chemicals, Inc. has control of, and is commissioning, the first four Trains of the Liquefaction Project. Pre-commercial LNG Marketing Agreement In May 2015, we entered into an agreement with Cheniere Marketing that authorizes Cheniere Marketing to act on our behalf to market and sell pre-commercial LNG that has not been accepted by BG Gulf Coast LNG, LLC. Services Agreements We recorded general and administrative expense—affiliate of $57.8 million and $52.3 million and operating and maintenance expense—affiliate of $0.5 million and $34,000 during the nine months ended September 30, 2015 and 2014 , respectively, under the services agreements listed below. Liquefaction O&M Agreement We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the Liquefaction Project is operational, the services include all necessary services required to operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month, which is recorded as general and administrative expense—affiliate on our Statements of Operations . After substantial completion of each Train, for services performed while the Liquefaction Project is operational, we will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to such Train. 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 Project, excluding those matters provided for under the Liquefaction O&M Agreement . The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project . Under the Liquefaction MSA , we pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month, which is recorded as general and administrative expense—affiliate on our Statements of Operations . After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train. LNG Site Sublease Agreement We have entered into agreements with SPLNG to sublease a portion of the Sabine Pass LNG terminal site for the Liquefaction Project. The annual sublease payment is $1.0 million . The initial term of the sublease expires on December 31, 2034, with options to renew for multiple 10 -year extensions with similar terms as the initial term. The annual sublease payment will be adjusted for inflation every 5 years based on a consumer price index, as defined in the sublease agreement. We recorded $0.5 million and $0.4 million of sublease expense as general and administrative expense—affiliate on our Statements of Operations for the nine months ended September 30, 2015 and 2014 , respectively. Cooperation Agreement We have entered into an agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project. In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. Under this agreement, we conveyed to SPLNG $80.5 million and $0.7 million of assets for the nine months ended September 30, 2015 and 2014, respectively. Interconnect Agreement We have entered into an agreement with CTPL to construct certain interconnect facilities between a 94 -mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines and the Liquefaction Project , with ownership and responsibility for maintenance and operation being transferred to CTPL following construction. Upon completion of construction activities during the three months ended September 30, 2015 , we conveyed to CTPL $10.1 million of assets under this agreement for the nine months ended September 30, 2015. 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.	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

Leases	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	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 Informat

Supplemental Cash Flow Information	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table (in thousands) provides supplemental disclosure of cash flow information: Nine Months Ended September 30, 2015 2014 Cash paid during the year for interest, net of amounts capitalized and deferred $ 13,471 $ — Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) 358,299 270,761 Non-cash distributions to affiliates for conveyance of assets 90,645 745 Other non-cash distribution to affiliates 149 — Non-cash conveyance of assets to non-affiliate 13,169 —	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

Recent Accounting Standards

Recent Accounting Standards	9 Months Ended
	Sep. 30, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards	RECENT ACCOUNTING STANDARDS In May 2014, the FASB amended its guidance on revenue recognition. The core principle of this amendment is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Earlier adoption is permitted as of annual reporting periods beginning after December 15, 2016. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. In August 2014, the FASB issued authoritative guidance that requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. This guidance is effective for annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter, with earlier adoption permitted. The adoption of this guidance is not expected to have an impact on our Financial Statements or related disclosures. In April 2015, the FASB issued authoritative guidance that requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. In August 2015, the FASB further issued guidance clarifying the SEC staff’s position on presentation and subsequent measurement of debt issuance costs incurred in connection with line of credit arrangements. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance must be adopted retrospectively to each prior reporting period presented and disclosures will be required for a change in accounting principles. We are currently evaluating the impact of the provisions of this guidance on our Balance Sheets. In July 2015, the FASB issued revised guidance related to the measurement of inventory. Inventory would be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption permitted. This guidance should be adopted prospectively. We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.

Quarterly Financial Data (unaud

Quarterly Financial Data (unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Quarterly Financial Data—(in thousands) First Quarter Second Quarter Third Quarter Fourth 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 )

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. 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.	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.
Income Taxes, Policy	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.	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.

Summary of Significant Accoun22

Summary of Significant Accounting Policies (Policies)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. 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.	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 no t 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	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.	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 (

Property, Plant and Equipment (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	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): September 30, December 31, 2015 2014 LNG terminal costs LNG terminal $ 13,171 $ 12,821 LNG terminal construction-in-process 9,187,749 6,946,242 Accumulated depreciation (540 ) (260 ) Total LNG terminal costs, net 9,200,380 6,958,803 Fixed assets Furniture and fixtures 1,154 1,154 Vehicles 1,379 854 Machinery and equipment 339 339 Other 4,358 2,292 Accumulated depreciation (2,046 ) (1,047 ) Total fixed assets, net 5,184 3,592 Property, plant and equipment, net $ 9,205,564 $ 6,962,395	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)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	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 instruments that are required to be measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of September 30, 2015 December 31, 2014 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Natural Gas Derivatives asset $ — $ 423 $ — $ 423 $ — $ 1,071 $ — $ 1,071 Liquefaction Supply Derivatives asset — — 32,546 32,546 — — 342 342 Interest Rate Derivatives liability — (15,738 ) — (15,738 ) — (12,036 ) — (12,036 )	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 December 31, 2014 December 31, 2013 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total 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 Inputs, Assets, Quantitative Information	The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2015 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Liquefaction Supply Derivatives $32,546 Income Approach Basis Spread $ (0.350) - $0.050	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 Net Presentation on Balance Sheets	The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of September 30, 2015 Natural Gas Derivatives $ 460 $ (37 ) $ 423 Liquefaction Supply Derivatives 33,028 — 33,028 Liquefaction Supply Derivatives (482 ) — (482 ) Interest Rate Derivatives (15,738 ) — (15,738 ) As of December 31, 2014 Natural Gas Derivatives 1,079 (8 ) 1,071 Liquefaction Supply Derivatives 662 — 662 Liquefaction Supply Derivatives (320 ) — (320 ) Interest Rate Derivatives 11,158 — 11,158 Interest Rate Derivatives (23,194 ) — (23,194 )	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 )
Commodity Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets: September 30, 2015 December 31, 2014 Natural Gas Derivatives (1) Liquefaction Supply Derivatives Total Natural Gas Derivatives (1) Liquefaction Supply Derivatives Total Balance Sheet Location Other current assets $ 423 $ 2,371 $ 2,794 $ 1,071 $ 76 $ 1,147 Non-current derivative assets — 30,657 30,657 — 586 586 Total derivative assets 423 33,028 33,451 1,071 662 1,733 Derivative liabilities — (349 ) (349 ) — (53 ) (53 ) Non-current derivative liabilities — (133 ) (133 ) — (267 ) (267 ) Total derivative liabilities — (482 ) (482 ) — (320 ) (320 ) Derivative asset, net $ 423 $ 32,546 $ 32,969 $ 1,071 $ 342 $ 1,413 (1) Does not include collateral calls of $0.3 million and $1.0 million for such contracts, which are included in other current assets in our Balance Sheets as of September 30, 2015 and December 31, 2014 , respectively.	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 and location of our Commodity Derivatives recorded in operating and maintenance expense (income) on our Statements of Operations during the nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, 2015 2014 Natural Gas Derivatives gain (loss) $ 1,221 $ (448 ) Liquefaction Supply Derivatives gain (1) 32,184 — (1) There were no physical settlements during the reporting period.	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.
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions	At September 30, 2015 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $20.0 million $628.8 million August 14, 2012 July 31, 2019 1.98% One-month LIBOR	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
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in thousands) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location September 30, 2015 December 31, 2014 Interest Rate Derivatives Derivative liabilities $ (7,039 ) $ (23,194 ) Interest Rate Derivatives Non-current derivative assets (Non-current derivative liabilities) (8,699 ) 11,158	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 )
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Statements of Operations during the nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, 2015 2014 Interest Rate Derivatives gain (loss) $ (46,541 ) $ (89,222 )	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
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 December 31, 2012 Interest Rate Derivatives - Designated $ (21,290 ) $ — $ — Interest Rate Derivatives - De-designated (5,814 ) — — Interest Rate Derivatives - Settlements (136 ) — — December 31, 2013 Interest Rate Derivatives - Designated 21,297 — 5,807 Interest Rate Derivatives - Settlements (30 ) — 166 December 31, 2014 Interest Rate Derivatives - Designated — — — Interest Rate Derivatives - De-designated — — — Interest Rate Derivatives - Settlements — — —

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Accrued Liabilities [Abstract]
Schedule of Accrued Liabilities	As of September 30, 2015 and December 31, 2014 , accrued liabilities consisted of the following (in thousands): September 30, December 31, 2015 2014 Interest expense and related debt fees $ 113,267 $ 97,785 Liquefaction Project costs 177,556 15,753 Total accrued liabilities $ 290,823 $ 113,538	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

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	As of September 30, 2015 and December 31, 2014 , our long-term debt consisted of the following (in thousands): Interest September 30, December 31, Rate 2015 2014 Long-term debt 2021 Senior Notes 5.625% $ 2,000,000 $ 2,000,000 2022 Senior Notes 6.250% 1,000,000 1,000,000 2023 Senior Notes 5.625% 1,500,000 1,500,000 2024 Senior Notes 5.750% 2,000,000 2,000,000 2025 Senior Notes 5.625% 2,000,000 — 2015 Credit Facilities (1) (2) 250,000 — Working Capital Facility (3) (4) — — Total long-term debt 8,750,000 6,500,000 Long-term debt premium 2021 Senior Notes 9,090 10,177 2023 Senior Notes 6,570 7,089 Total long-term debt, net $ 8,765,660 $ 6,517,266 (1) Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the Liquefaction Project. (2) Variable interest rate, at our election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75% , depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75% . Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter. (3) Matures on December 31, 2020, with various terms for underlying loans as further described below under Working Capital Facility . As of September 30, 2015 and December 31, 2014 , no loans were outstanding under the Working Capital Facility or the LC Agreement it replaced. (4) Variable interest rates, based on LIBOR or the base rate, as further described below under Working Capital Facility .	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: September 30, 2015 December 31, 2014 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value 2021 Senior Notes, net of premium (1) $ 2,009,090 $ 1,853,386 $ 2,010,177 $ 1,985,050 2022 Senior Notes (1) 1,000,000 930,000 1,000,000 1,020,000 2023 Senior Notes, net of premium (1) 1,506,570 1,344,614 1,507,089 1,476,947 2024 Senior Notes (1) 2,000,000 1,765,000 2,000,000 1,970,000 2025 Senior Notes (1) 2,000,000 1,755,000 — — 2015 Credit Facilities (2) 250,000 250,000 — — Working Capital Facility (2) — — — — (1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014 , as applicable. (2) The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.	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 Amount Estimated Fair Value Carrying Amount Estimated 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	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 Inform28

Supplemental Cash Flow Information (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table (in thousands) provides supplemental disclosure of cash flow information: Nine Months Ended September 30, 2015 2014 Cash paid during the year for interest, net of amounts capitalized and deferred $ 13,471 $ — Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) 358,299 270,761 Non-cash distributions to affiliates for conveyance of assets 90,645 745 Other non-cash distribution to affiliates 149 — Non-cash conveyance of assets to non-affiliate 13,169 —	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 (una29

Quarterly Financial Data (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Quarterly Financial Data—(in thousands) First Quarter Second Quarter Third Quarter Fourth 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 Op30

Organization and Nature of Operations (Details)	12 Months Ended
	Dec. 31, 2014itemmilliontonnes / yrbcf / dBcfetrainsm³
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 | Bcfe	16.9
Number Of Docks	2
Volume Of Vessel | m³	266,000
Regasification Capacity | bcf / d	4
Number of Liquefaction LNG Trains | trains	6
Train Nominal Capacity | milliontonnes / yr	4.5
Cheniere Partners [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 [Member]
Organization and Nature of Operations [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent	80.10%

Summary of Significant Accoun31

Summary of Significant Accounting Policies (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)	Dec. 31, 2014USD ($)item	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
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 | item		6
Sale and Purchase Agreement Term of Agreement		20 years
Sale and Purchase Agreement Number of Unaffiliated Counterparties | item		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 [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Income Taxes Paid, Net	$ 0	$ 0

Restricted Cash (Details)

Restricted Cash (Details) - USD ($)	1 Months Ended	12 Months Ended
	Apr. 30, 2013	Dec. 31, 2014	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	May. 31, 2014	Dec. 31, 2013	Nov. 30, 2013	May. 31, 2013	Jul. 31, 2012
Restricted Cash Items [Line Items]
Current restricted cash		$ 155,810,000	$ 327,150,000				$ 192,144,000
Non-current restricted cash		$ 457,053,000	$ 0				867,590,000
2012 Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity										$ 3,600,000,000
2013 Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity							5,900,000,000		$ 5,900,000,000
2015 Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				$ 4,600,000,000
2021 Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount	$ 2,000,000,000						$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%	5.625%				5.625%
Debt Instrument, Increase, Net	$ 500,000,000
2022 Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount							$ 1,000,000,000	$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%	6.25%				6.25%
2023 Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount						$ 1,500,000,000	$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%	5.625%				5.625%
Debt Instrument, Increase, Net		$ 500,000,000
2024 Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount		$ 2,000,000,000				$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%	5.75%
2025 Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount					$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage			5.625%		5.625%
Payment of Liabilities [Member]
Restricted Cash Items [Line Items]
Current restricted cash		$ 155,810,000	$ 327,150,000				$ 192,100,000
Construction Activities [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash		$ 457,053,000	$ 0				$ 867,600,000

Property, Plant and Equipment33

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 9,205,564	$ 6,962,395	$ 4,412,580
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(540)	(260)	0
Property, plant and equipment, net	9,200,380	6,958,803	4,412,175
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,171	12,821	98
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	9,187,749	6,946,242	4,412,077
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(2,046)	(1,047)	(340)
Property, plant and equipment, net	5,184	3,592	405
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,154	1,154	10
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,379	854	309
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	339	339	301
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 4,358	$ 2,292	$ 125

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) MMBTU in Millions	1 Months Ended			9 Months Ended		12 Months Ended
	Mar. 31, 2015USD ($)	May. 31, 2014USD ($)	Nov. 30, 2013USD ($)	Sep. 30, 2015USD ($)MMBTU	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)MMBTU	Dec. 31, 2013USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Asset Transfers into Level 3				$ 0	$ 0	$ 0	$ 0
Asset Transfers out of Level 3				$ 0	$ 0	$ 0	$ 0
Energy Units Secured Through Long-Term Purchase Agreements | MMBTU				2,156.6
2013 Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease	$ 1,800,000,000	$ 2,100,000,000	$ 885,000,000
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount | MMBTU				1,244.1		1,249.4
Liquefaction Supply Derivatives [Member] | Minimum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract				1 year		1 year
Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract				7 years		7 years
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net	$ 34,700,000	$ 9,300,000

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Natural Gas Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 423	$ 1,071	$ (156)
Natural Gas 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	0
Natural Gas 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	423	1,071	(156)
Natural Gas 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	0
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	32,546	342	0
Liquefaction 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	0
Liquefaction 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	0
Liquefaction 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	32,546	342	0
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(15,738)	(12,036)	84,639
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0	0
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(15,738)	(12,036)	84,639
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ 0	$ 0

Derivative Instruments - Fair36

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Liquefaction Supply Derivatives [Member] - USD ($)	9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 32,546,000		$ 342,000	$ 0
Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 32,546,000		342,000	$ 0
Valuation Technique	Income Approach	Basis Spread plus Liquid Location
Significant Unobservable Input	Basis Spread	Basis Spread
Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ (0.350)		(0.350)
Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ 0.050		$ 0.035

Derivative Instruments - Fair37

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Thousands		Sep. 30, 2015		Dec. 31, 2014		Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Non-current derivative assets		$ 30,657		$ 11,744		$ 98,123
Derivative liabilities		(7,388)		(23,247)		(13,484)
Non-current derivative liabilities		(8,832)		(268)		0
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		33,451		1,733
Total derivative liabilities		(482)		(320)
Derivative asset, net		32,969		1,413
Commodity Contract [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		2,794		1,147
Commodity Contract [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		30,657		586
Commodity Contract [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(349)		(53)
Commodity Contract [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(133)		(267)
Natural Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	423		1,071
Total derivative liabilities	[1]	0		0
Derivative asset, net	[1]	423		1,071
Natural Gas Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		423	[1]	1,071	[1]	156
Derivative, Collateral Call (Deposit), Right to Reclaim Cash		300		1,000		(200)
Natural Gas Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	[1]	0		0
Natural Gas Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	0		0
Natural Gas Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	[1]	0		0
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		33,028		662
Total derivative liabilities		(482)		(320)
Derivative asset, net		32,546		342
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		2,371		76		0
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		30,657		586		0
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(349)		(53)		0
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(133)		(267)		0
Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets				11,158		98,123
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(7,039)		$ (23,194)		$ (13,484)
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		$ (8,699)
[1]	Does not include collateral calls of $0.3 million and $1.0 million for such contracts, which are included in other current assets in our Balance Sheets as of September 30, 2015 and December 31, 2014, respectively.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($)

1 Months Ended

9 Months Ended

12 Months Ended

Mar. 31, 2015

May. 31, 2014

Sep. 30, 2015

Sep. 30, 2014

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Natural Gas Derivatives [Member] | Operating and maintenance expense (income) [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivative, Gain (Loss) on Derivative, Net

$ 1,221,000

$ (448,000)

Natural Gas Derivatives [Member] | Derivative gain (loss), net [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivative, Gain (Loss) on Derivative, Net

$ 860,000

$ 476,000

$ 0

Liquefaction Supply Derivatives [Member] | Operating and maintenance expense (income) [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivative, Gain (Loss) on Derivative, Net

32,184,000

[1]

0

[1]

342,000

[2]

0

[2]

0

[2]

Settlements during the period

0

0

0

0

0

Interest Rate Derivatives [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivative, Gain (Loss) on Derivative, Net

$ (34,700,000)

$ (9,300,000)

Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivative, Gain (Loss) on Derivative, Net

$ (46,541,000)

$ (89,222,000)

$ (119,401,000)

$ 88,596,000

$ 679,000

[1]

There were no physical settlements during the reporting period.

[2]

There were no settlements during the reporting period.

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - Interest Rate Derivatives [Member] - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 20	$ 20
Effective Date	Aug. 14, 2012	Aug. 14, 2012
Maturity Date	Jul. 31, 2019	Jul. 31, 2019
Weighted Average Fixed Interest Rate Paid	1.98%	1.98%
Variable Interest Rate Received	One-month LIBOR	One-month LIBOR
Maximum [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 628.8	$ 2,500

Derivative Instruments - Sche40

Derivative Instruments - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Details) - Interest Rate Derivatives [Member] - USD ($) $ in Thousands	12 Months Ended
	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 - Deri41

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Natural Gas Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 460	$ 1,079
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(37)	(8)
Net Amounts Presented in our Balance Sheets	423	1,071
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		0
Derivative, Collateral, Right to Reclaim Cash		0
Natural Gas Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized			$ (156)
Derivative Liability, Gross Amounts Offset in the Balance Sheets			(156)
Net Amounts Presented in our Balance Sheets			0
Derivative Liability, Fair Value, Amount Not Offset Against Collateral			0
Derivative, Collateral, Right to Reclaim Cash			0
Derivative Liability			0
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	33,028	662
Derivative Asset, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	33,028	662
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		0
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Asset		662
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(482)	(320)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	(482)	(320)
Derivative Liability, Fair Value, Amount Not Offset Against Collateral		0
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		(320)
Interest Rate Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		11,158	98,123
Derivative Asset, Gross Amounts Offset in the Balance Sheets		0	0
Net Amounts Presented in our Balance Sheets		11,158	98,123
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		0	0
Derivative, Collateral, Right to Reclaim Cash		0	0
Derivative Asset		11,158	98,123
Interest Rate Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(15,738)	(23,194)	(13,484)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	0	0	0
Net Amounts Presented in our Balance Sheets	$ (15,738)	(23,194)	(13,484)
Derivative Liability, Fair Value, Amount Not Offset Against Collateral		0	0
Derivative, Collateral, Right to Reclaim Cash		0	0
Derivative Liability		(23,194)	$ (13,484)
Scenario, Previously Reported [Member] | Natural Gas Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		1,071
Derivative Asset, Gross Amounts Offset in the Balance Sheets		1,000
Net Amounts Presented in our Balance Sheets		71
Derivative Asset		$ 71

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$ 113,267	$ 97,785	$ 65,153
Liquefaction Project costs	177,556	15,753	79,422
Total accrued liabilities	$ 290,823	$ 113,538	$ 144,575

Long-Term Debt - Schedule of Lo

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) - USD ($) $ in Thousands		9 Months Ended		12 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 8,750,000		$ 6,500,000	$ 4,100,000
Total Long-Term Debt, Net		8,765,660		6,517,266	4,111,562
Interest Costs Incurred		388,000	$ 288,300	397,900	241,300	$ 35,300
Interest Costs Capitalized		356,700	$ 271,500	374,000	227,900	$ 35,100
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		2,000,000		2,000,000	2,000,000
Debt Instrument, Unamortized Premium		$ 9,090		$ 10,177	$ 11,562
Debt Instrument, Interest Rate, Stated Percentage		5.625%		5.625%	5.625%
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,000,000		$ 1,000,000	$ 1,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%		6.25%	6.25%
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,500,000		$ 1,500,000	$ 1,000,000
Debt Instrument, Unamortized Premium		$ 6,570		$ 7,089	$ 0
Debt Instrument, Interest Rate, Stated Percentage		5.625%		5.625%	5.625%
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 2,000,000		$ 2,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage		5.75%		5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 2,000,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage		5.625%					5.625%
2013 Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				$ 0	$ 100,000
Debt Instrument, Description of Variable Rate Basis				LIBOR
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1],[2]	$ 250,000		$ 0
Debt Instrument, Description of Variable Rate Basis		LIBOR
2015 Credit Facilities [Member] | LIBOR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.30%
2015 Credit Facilities [Member] | LIBOR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
2015 Credit Facilities [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[3],[4]	$ 0		$ 0
[1]	Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the Liquefaction Project.
[2]	Variable interest rate, at our election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.
[3]	Matures on December 31, 2020, with various terms for underlying loans as further described below under Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the Working Capital Facility or the LC Agreement it replaced.
[4]	Variable interest rates, based on LIBOR or the base rate, as further described below under Working Capital Facility.

Long-Term Debt - Schedule of Ma

Long-Term Debt - Schedule of Maturities (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Total	$ 8,750,000	$ 6,500,000	$ 4,100,000
2,015		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	2,000,000
2,015		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	1,000,000
2,015		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	1,500,000	1,000,000
2,015		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	2,000,000	$ 0
2,015		0
2016 to 2017		0
2018 to 2019		0
Thereafter		$ 2,000,000

Long-Term Debt - Senior Notes (

Long-Term Debt - Senior Notes (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014USD ($)Rate	Mar. 31, 2015USD ($)	May. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Nov. 30, 2013USD ($)	Apr. 30, 2013USD ($)
Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Fixed Charge, Coverage Ratio Period		12 months
Debt Instrument, Fixed Charge, Coverage Ratio | Rate		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		$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%			5.625%
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount					$ 1,000,000,000	$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%			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	5.625%	5.625%			5.625%
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 2,000,000,000		$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%		5.625%
Debt Instrument Registration Period	360 days

Long-Term Debt - Credit Facilit

Long-Term Debt - Credit Facilities (Details) - USD ($) $ in Thousands

1 Months Ended

9 Months Ended

12 Months Ended

Mar. 31, 2015

May. 31, 2014

Nov. 30, 2013

Jun. 30, 2013

May. 31, 2013

Apr. 30, 2013

Sep. 30, 2015

Sep. 30, 2014

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2015

Jul. 31, 2012

Line of Credit Facility [Line Items]

Long-term Debt, Outstanding Borrowings

$ 8,750,000

$ 6,500,000

$ 4,100,000

Loss on extinguishment of debt

96,273

$ 114,335

114,335

131,576

$ 0

2015 Credit Facilities [Member]

Line of Credit Facility [Line Items]

Maximum Borrowing Capacity

$ 4,600,000

Line of Credit Facility, Remaining Borrowing Capacity

4,300,000

Long-term Debt, Outstanding Borrowings

[1],[2]

250,000

0

Debt Instrument, Fee Amount

$ 88,200

Line Of Credit Facility Insurance Premium Percentage Of Drawn Amount

0.45%

Line Of Credit Facility, Commitment Fee, Percentage Of Margin On Undrawn Commitment, per annum

40.00%

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage, per annum

0.70%

Line of Credit Facility, Amortization Period

18 years

Debt Instrument, Description of Variable Rate Basis

LIBOR

2015 Credit Facilities [Member] | Minimum [Member]

Line of Credit Facility [Line Items]

Percentage of Debt Hedged by Interest Rate Derivatives

65.00%

2013 Credit Facilities [Member]

Line of Credit Facility [Line Items]

Maximum Borrowing Capacity

$ 5,900,000

5,900,000

Line of Credit Facility, Remaining Borrowing Capacity

2,700,000

4,900,000

Long-term Debt, Outstanding Borrowings

0

100,000

Debt Instrument, Fee Amount

$ 144,000

Line Of Credit Facility, Commitment Fee, Percentage Of Margin On Undrawn Commitment, per annum

40.00%

Line of Credit Facility, Amortization Period

18 years

Debt Instrument, Description of Variable Rate Basis

LIBOR

Proceeds from (Repayments of) Lines of Credit

$ 100,000

Line of Credit Facility, Decrease

$ 1,800,000

$ 2,100,000

$ 885,000

Loss on extinguishment of debt

$ 114,300

$ 43,300

$ 96,300

2013 Credit Facilities [Member] | Minimum [Member]

Line of Credit Facility [Line Items]

Percentage of Debt Hedged by Interest Rate Derivatives

75.00%

2013 Credit Facilities [Member] | Construction [Member] | Minimum [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

2.30%

2013 Credit Facilities [Member] | Construction [Member] | Maximum [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

3.00%

2013 Credit Facilities [Member] | Operations [Member] | Minimum [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

2.30%

2013 Credit Facilities [Member] | Operations [Member] | Maximum [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

3.25%

2012 Credit Facilities [Member]

Line of Credit Facility [Line Items]

Maximum Borrowing Capacity

$ 3,600,000

Debt Instrument, Description of Variable Rate Basis

LIBOR

Line of Credit Facility, Decrease

$ 100,000

$ 1,400,000

Loss on extinguishment of debt

88,300

2012 Credit Facilities [Member] | Minimum [Member]

Line of Credit Facility [Line Items]

Percentage of Debt Hedged by Interest Rate Derivatives

75.00%

2012 Credit Facilities [Member] | Construction [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

3.50%

2012 Credit Facilities [Member] | Operations [Member]

Line of Credit Facility [Line Items]

Debt Instrument, Basis Spread on Variable Rate

3.75%

2021 Senior Notes [Member]

Line of Credit Facility [Line Items]

Long-term Debt, Outstanding Borrowings

$ 2,000,000

$ 2,000,000

$ 2,000,000

Debt Instrument, Increase, Net

$ 500,000

[1]

Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the Liquefaction Project.

[2]

Variable interest rate, at our election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

Long-Term Debt - Working Capita

Long-Term Debt - Working Capital Facility (Details) - USD ($)		9 Months Ended	12 Months Ended
		Sep. 30, 2015	Dec. 31, 2014	Apr. 30, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 8,750,000,000	$ 6,500,000,000		$ 4,100,000,000
LC Agreement [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity				$ 325,000,000
Letters of Credit, Outstanding Amount			9,500,000
Letters of Credit, Drawn Amount			0
Working Capital Facility [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity		1,200,000,000
Line of Credit Facility, Remaining Borrowing Capacity		1,100,000,000
Long-term Debt, Outstanding Borrowings	[1],[2]	0	0
Debt Instrument, Fee Amount		$ 27,500,000
Line of Credit Facility, Number of Business Days Notice Required for Repayment of Debt Without Penalty		3 days
Working Capital Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Permitted Increase		$ 760,000,000
Working Capital Facility [Member] | Completion of Train Six Financing [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Permitted Increase		390,000,000
Letters of Credit [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity				$ 325,000,000
Letters of Credit, Outstanding Amount		127,600,000	9,500,000
Letters of Credit, Drawn Amount		$ 0	$ 0
Debt Instrument, Basis Spread on Variable Rate			2.00%
Letters of Credit [Member] | Unissued Portion [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage			0.75%
Letters of Credit [Member] | Undrawn Portion [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage		1.75%	2.50%
Letters of Credit [Member] | Drawn Portion [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.00%
Working Capital Facility Loan [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage, per annum		0.70%
Working Capital Facility Loan [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
Working Capital Facility Loan [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.75%
Working Capital Facility Loan [Member] | Base Rate Determination Federal Funds Rate [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Working Capital Facility Loan [Member] | Base Rate Determination LIBOR [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Working Capital Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
Line of Credit Facility, Annual Temporary Requirement Balance, Outstanding Principal		$ 0
Line of Credit Facility, Annual Temporary Requirement Period, Number of Consecutive Business Days		5 days
Swing Line Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
Debt Instrument, Term		15 days
Line of Credit Facility, Minimum Period For Termination Date, Number of Business Days		3 days
LC Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
LC Loan [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term		1 year
[1]	Matures on December 31, 2020, with various terms for underlying loans as further described below under Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the Working Capital Facility or the LC Agreement it replaced.
[2]	Variable interest rates, based on LIBOR or the base rate, as further described below under Working Capital Facility.

Long-Term Debt - Schedule of Ca

Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Thousands		Sep. 30, 2015		Dec. 31, 2014		Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		$ 8,765,660		$ 6,517,266		$ 4,111,562
2021 Senior Notes, net of premium [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		2,009,090		2,010,177		2,011,562
2021 Senior Notes, net of premium [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure		1,853,386	[1]	1,985,050	[1],[2]	1,961,273	[2]
2022 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		1,000,000		1,000,000		1,000,000
2022 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure		930,000	[1]	1,020,000	[1],[2]	982,500	[2]
2023 Senior Notes, net of premium [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		1,506,570		1,507,089		1,000,000
2023 Senior Notes, net of premium [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure		1,344,614	[1]	1,476,947	[1],[2]	935,000	[2]
2024 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		2,000,000		2,000,000		0
2024 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure		1,765,000	[1]	1,970,000	[1],[2]	0	[2]
2025 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		2,000,000		0
2025 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,755,000		0
2015 Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		250,000		0
2015 Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[3]	250,000		0
Working Capital Facility [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt		0		0
Working Capital Facility [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[3]	$ 0		0
2013 Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term Debt				0		100,000
2013 Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[4]			$ 0		$ 100,000
[1]	The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014, as applicable.
[2]	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.
[3]	The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.
[4]	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)	9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)bcfmi$ / MMBTU	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)bcf / d$ / MMBTU	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Related Party Transaction [Line Items]
General and administrative expense—affiliate	$ 58,304,000	$ 52,644,000	$ 71,065,000	$ 93,064,000	$ 33,951,000
Operating and maintenance expense—affiliate	$ 456,000	34,000	95,000	0	0
LNG Terminal Capacity Agreements [Member]
Related Party Transaction [Line Items]
Terminal Use Agreement Maintenance Expense Including Affiliate			$ 26,700,000	26,600,000	10,100,000
LNG Terminal Capacity Agreements [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Regasification Capacity	2		2
Related Party Transaction, Committed Annual Fee	$ 250,000,000		$ 250,000,000
Related Party Agreement Term	20 years		20 years
Portion of Storage Capacity Reserved	41.00%		41.00%
Terminal Use Agreement Maintenance Expense Including Affiliate	$ 17,000,000	25,000,000
LNG Terminal Capacity Agreements [Member] | SPLNG [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	100.00%		100.00%
LNG Terminal Capacity Agreements [Member] | SPLNG [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	0.00%		0.00%
LNG Sale and Purchase Agreement [Member] | Cheniere Marketing [Member]
Related Party Transaction [Line Items]
Incremental LNG Volume, Purchase Price Percentage of Henry Hub	115.00%		115.00%
Incremental LNG Volume, Purchase Price | $ / MMBTU	3		3
Service Agreements [Member]
Related Party Transaction [Line Items]
General and administrative expense—affiliate	$ 57,800,000	52,300,000	$ 70,600,000	92,600,000	34,000,000
Operating and maintenance expense—affiliate	$ 500,000	34,000
Operation and Maintenance Agreement [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	0.60%		0.60%
Related Party Transaction, Committed Monthly Fee	$ 83,333		$ 83,333
Management Services Agreement [Member] | Cheniere Terminals [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	2.40%		2.40%
Related Party Transaction, Committed Monthly Fee	$ 541,667		$ 541,667
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment	$ 1,000,000
Term of available extension	10 years		10 years
Review Period for Inflation Adjustment	5 years		5 years
Operating Leases, Sublease Rent Expense, Net	$ 500,000	400,000	$ 500,000	$ 500,000	$ 300,000
Cooperation Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement	80,500,000	$ 700,000	700,000
Interconnect Agreement [Member] | CTPL [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement	$ 10,100,000
Interconnect Agreement [Member] | CTPL [Member] | Creole Trail Pipeline [Member]
Related Party Transaction [Line Items]
Length of Natural Gas Pipeline | mi	94
Tax Sharing Agreement [Member] | Cheniere [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net	$ 0		$ 0

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)alease_extension	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Operating Leased Assets [Line Items]
Operating Leases, Rent Expense | $			$ 0.9	$ 0.9	$ 0.7
Land [Member]
Operating Leased Assets [Line Items]
Acreage Under Lease | a			80.7
Property Lease Term			5 years
Number Of Available Lease Extensions			5
Term of available extension			1 year
Land 2 [Member]
Operating Leased Assets [Line Items]
Acreage Under Lease | a			80.6
Property Lease Term			30 years
Number Of Available Lease Extensions			6
Term of available extension			10 years
Review Period for Inflation Adjustment			5 years
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Operating Leased Assets [Line Items]
Number Of Available Lease Extensions			5
Term of available extension	10 years		10 years
Review Period for Inflation Adjustment	5 years		5 years
Annual Sublease Payment | $			$ 0.5
Operating Leases, Sublease Rent Expense, Net | $	$ 0.5	$ 0.4	$ 0.5	$ 0.5	$ 0.3

Leases - Schedule of Future Min

Leases - Schedule of Future Minimum Rental Payments (Details) $ in Thousands	Dec. 31, 2014USD ($)
Leases [Abstract]
2,015	$ 908
2,016	874
2,017	770
2,018	770
2,019	770
Thereafter	53,606	[1]
Total	$ 57,698
[1]	Includes certain lease option renewals as they are reasonably assured.

Commitments and Contingencies (

Commitments and Contingencies (Details) MMBTU / yr in Millions, $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)bcf	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)bcf / dMMBTU / yritemunit	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Commitments and Contingencies [Line Items]
Sale and Purchase Agreement Number of Unaffiliated Counterparties | item			6
Loss Contingency, Pending Claims, Number | unit			0
Bechtel EPC Contract - Train One And Two [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Amount			$ 3,900
Bechtel EPC Contract - Train One And Two [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Contract Termination Convenience Penalty			30
Bechtel EPC Contract - Train Three And Four [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Amount			3,800
Bechtel EPC Contract - Train Three And Four [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Contract Termination Convenience Penalty			$ 30
Fixed Price Contract Trains 1 Through 4 [Member]
Commitments and Contingencies [Line Items]
Sale and Purchase Agreement Number of Unaffiliated Counterparties | unit			4
Contract Volumes | MMBTU / yr			834
Fixed Price Contract Train 5 [Member]
Commitments and Contingencies [Line Items]
Sale and Purchase Agreement Number of Unaffiliated Counterparties | unit			2
Contract Volumes | MMBTU / yr			196
LNG Terminal Capacity Agreements [Member]
Commitments and Contingencies [Line Items]
Terminal Use Agreement Maintenance Expense Including Affiliate			$ 26.7	$ 26.6	$ 10.1
LNG Terminal Capacity Agreements [Member] | SPLNG [Member]
Commitments and Contingencies [Line Items]
Regasification Capacity	2		2
Related Party Transaction, Committed Annual Fee	$ 250		$ 250
Related Party Agreement Term	20 years		20 years
Portion of Storage Capacity Reserved	41.00%		41.00%
Terminal Use Agreement Maintenance Expense Including Affiliate	$ 17	$ 25
LNG Terminal Capacity Agreements [Member] | SPLNG [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	100.00%		100.00%
LNG Terminal Capacity Agreements [Member] | SPLNG [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	0.00%		0.00%

Supplemental Cash Flow Inform53

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized and deferred	$ 13,471	$ 0
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	358,299	270,761	$ 117,442	$ 163,830	$ 99,680
Non-cash distributions to affiliates for conveyance of assets	90,645	745
Other non-cash distribution to affiliates	149	0
Non-cash conveyance of assets to non-affiliate	$ 13,169	$ 0

Quarterly Financial Data (una54

Quarterly Financial Data (unaudited) (Details) - USD ($) $ in Thousands	3 Months Ended								9 Months Ended		12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2015	Sep. 30, 2014	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	$ 0	$ 0
Loss from operations	(24,046)	(32,365)	(38,640)	(24,988)	(29,724)	(50,842)	(39,756)	(15,814)	(56,730)	(96,441)	(120,039)	(136,136)	(85,783)
Net loss	$ (59,977)	$ (43,559)	$ (213,477)	$ (59,840)	$ (51,408)	$ (73,036)	$ (36,185)	$ (33,861)	$ (230,485)	$ (316,876)	$ (376,853)	$ (194,490)	$ (85,157)