Sabine Pass Liquefaction 10-Q 3 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2016shares
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Central Index Key	1,499,200
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding	0

Balance Sheets

Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 0	$ 0
Restricted cash	325,630	189,260
Accounts and other receivables	50,966	577
Accounts receivable—affiliate	56,986	2,457
Advances to affiliate	31,002	28,312
Inventory	51,715	5,742
Other current assets	11,256	8,412
Other current assets—affiliate	5,293	0
Total current assets	532,848	234,760
Property, plant and equipment, net	11,491,279	9,841,407
Debt issuance costs, net	62,349	132,091
Non-current derivative assets	11,247	30,304
Other non-current assets	179,832	194,818
Total assets	12,277,555	10,433,380
Current liabilities
Accounts payable	17,130	13,420
Accrued liabilities	326,815	201,559
Current debt	98,500	15,000
Due to affiliates	42,556	53,848
Derivative liabilities	7,459	6,430
Total current liabilities	492,460	290,257
Long-term debt, net	11,330,473	9,205,559
Non-current derivative liabilities	9,583	2,884
Other non-current liabilities—affiliate	3,578	3,393
Member’s equity	441,461	931,287
Total liabilities and member’s equity	$ 12,277,555	$ 10,433,380

Statements of Operations

Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues
LNG revenues	$ 248,188	$ 0	$ 333,542	$ 0
LNG revenues—affiliate	16,236	0	16,236	0
Total revenues	264,424	0	349,778	0
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	161,829	(32,106)	217,567	(32,176)
Cost of sales—affiliate	3,245	0	3,890	0
Operating and maintenance expense	24,588	1,623	40,606	4,655
Operating and maintenance expense—affiliate	43,468	328	66,230	456
Terminal use agreement maintenance expense (recovery)	72	(837)	(546)	16,684
Terminal use agreement maintenance expense—affiliate	0	130	208	308
Development expense	1	113	137	2,631
Development expense—affiliate	87	152	484	562
General and administrative expense	1,818	1,307	5,472	4,027
General and administrative expense—affiliate	18,942	18,938	51,824	58,304
Depreciation and amortization expense	25,749	461	37,863	1,279
Total operating costs and expenses (recoveries)	279,799	(9,891)	423,735	56,730
Income (loss) from operations	(15,375)	9,891	(73,957)	(56,730)
Other income (expense)
Interest expense, net of capitalized interest	(65,939)	(11,952)	(99,203)	(31,261)
Loss on early extinguishment of debt	(25,765)	0	(52,070)	(96,273)
Derivative gain (loss), net	2,557	(10,872)	(13,473)	(46,541)
Other income	179	98	429	320
Total other expense	(88,968)	(22,726)	(164,317)	(173,755)
Net loss	$ (104,343)	$ (12,835)	$ (238,274)	$ (230,485)

Statement of Member's Equity

Statement of Member's Equity - 9 months ended Sep. 30, 2016 - USD ($) $ in Thousands	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2015	$ 931,287	$ 931,287
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	1,250	1,250
Non-cash distributions to affiliates	(252,802)	(252,802)
Net loss	(238,274)	(238,274)
Member's equity, end of period at Sep. 30, 2016	$ 441,461	$ 441,461

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows from operating activities
Net loss	$ (238,274)	$ (230,485)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Non-cash terminal use agreement maintenance expense	160	16,610
Depreciation and amortization expense	37,863	1,279
Loss on early extinguishment of debt	52,070	96,273
Total losses on derivatives, net	35,635	13,136
Net cash used for settlement of derivative instruments	(8,031)	(40,990)
Changes in restricted cash for certain operating activities	157,291	230,187
Changes in operating assets and liabilities:
Accounts and other receivables	(31,022)	8
Accounts receivable—affiliate	(36,650)	(78)
Advances to affiliate	0	(12,654)
Inventory	(28,296)	(41)
Accounts payable and accrued liabilities	67,039	(42,179)
Due to affiliates	3,885	(10,029)
Other, net	(7,044)	(1,840)
Other—affiliate	(4,626)	(19,197)
Net cash provided by (used in) operating activities	0	0
Cash flows from investing activities
Property, plant and equipment, net	(1,872,975)	(2,094,567)
Use of restricted cash for the acquisition of property, plant and equipment	1,905,102	2,144,821
Other	(32,127)	(50,254)
Net cash provided by (used in) investing activities	0	0
Cash flows from financing activities
Proceeds from issuances of debt	4,968,500	2,250,000
Repayments of debt	(2,730,000)	0
Debt issuance and deferred financing costs	(40,693)	(176,002)
Investment in restricted cash	(2,198,763)	(2,089,295)
Capital contributions from Cheniere Partners	1,250	15,297
Other	(294)	0
Net cash provided by (used in) financing activities	0	0
Net increase (decrease) in cash and cash equivalents	0	0
Cash and cash equivalents—beginning of period	0	0
Cash and cash equivalents—end of period	$ 0	$ 0

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2016
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 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, operating results or cash flows. In 2016, we started production at our natural gas liquefaction facilities at the Sabine Pass LNG terminal located in Cameron Parish, Louisiana (the “Liquefaction Project”) . As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project , and other related costs to convert natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities. During the three and nine months ended September 30, 2016 , we received 70% and 77% , respectively, of our net LNG revenues from one SPA customer. Results of operations for the three and nine months ended September 30, 2016 are not necessarily indicative of the operating results that will be realized for the year ending December 31, 2016 . 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, 2015 .

Restricted Cash

Restricted Cash	9 Months Ended
	Sep. 30, 2016
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. As of September 30, 2016 and December 31, 2015 , restricted cash consisted of the following (in thousands): September 30, December 31, 2016 2015 Current restricted cash Liquefaction Project $ 325,630 $ 189,260

Accounts and Other Receivables

Accounts and Other Receivables	9 Months Ended
	Sep. 30, 2016
Receivables [Abstract]
Accounts and Other Receivables	ACCOUNTS AND OTHER RECEIVABLES As of September 30, 2016 and December 31, 2015 , accounts and other receivables consisted of the following (in thousands): September 30, December 31, 2016 2015 Trade receivable $ 38,432 $ — Interest receivable 53 7 Other accounts receivable 12,481 570 Total accounts and other receivables $ 50,966 $ 577 Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments. As of September 30, 2016 , the entire balance of our trade receivable was from a single SPA customer.

Inventory

Inventory	9 Months Ended
	Sep. 30, 2016
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of September 30, 2016 and December 31, 2015 , inventory consisted of the following (in thousands): September 30, December 31, 2016 2015 Natural gas $ 4,181 $ 5,724 LNG 25,280 — Materials and other 22,254 18 Total inventory $ 51,715 $ 5,742

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2016
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, 2016 2015 LNG terminal costs LNG terminal $ 5,264,538 $ 42,220 LNG terminal construction-in-process 6,254,085 9,795,309 Accumulated depreciation (32,493 ) (789 ) Total LNG terminal costs, net 11,486,130 9,836,740 Fixed assets Furniture and fixtures 1,446 1,154 Computer software 4,144 3,782 Machinery and equipment 405 339 Vehicles 2,419 1,405 Other 720 390 Accumulated depreciation (3,985 ) (2,403 ) Total fixed assets, net 5,149 4,667 Property, plant and equipment, net $ 11,491,279 $ 9,841,407 During the three and nine months ended September 30, 2016 , we realized offsets to LNG terminal costs of $58.7 million and $201.0 million , respectively, that were related to the sale of commissioning cargoes because these amounts were earned prior to the start of commercial operations, during the testing phase for the construction of Trains 1 and 2 of the Liquefaction Project .

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2016
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: • interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under one of our credit facilities (“Interest Rate Derivatives”) ; • commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives”, and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”) ; and • commodity derivatives to hedge the exposure to price risk attributable to future sales of our LNG inventory (“Natural Gas 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 the derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2016 and December 31, 2015 , 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, 2016 December 31, 2015 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 Interest Rate Derivatives liability $ — $ (15,948 ) $ — $ (15,948 ) $ — $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives asset (liability) (105 ) (275 ) 12,480 12,100 — (25 ) 32,492 32,467 Natural Gas Derivatives asset — — — — — 29 — 29 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 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. The fair value of substantially all of our Physical 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 Physical Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of our Physical 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 Physical 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 include conditions precedent to the respective long-term natural gas supply contracts. As of September 30, 2016 and December 31, 2015 , some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow. Accordingly, our internal fair value models are based on market prices that equate 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 Physical 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 supply contracts as of the reporting date. 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 our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2016 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $12,480 Income Approach Basis Spread $(0.35) - $(0.03) The following table (in thousands) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2016 and 2015 : Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Balance, beginning of period $ 22,434 $ 440 $ 32,492 $ 342 Realized and mark-to-market losses: Included in cost of sales (1) (10,567 ) 32,177 (20,482 ) 32,204 Purchases and settlements: Purchases 968 — 968 — Settlements (1) (308 ) (71 ) (741 ) — Transfers out of Level 3 (2) (47 ) — 243 — Balance, end of period $ 12,480 $ 32,546 $ 12,480 $ 32,546 Change in unrealized gains relating to instruments still held at end of period $ (10,567 ) $ — $ (19,763 ) $ — (1) Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the nine months ended September 30, 2016 . (2) Transferred to Level 2 as a result of observable market for the underlying natural gas supply contracts. 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. 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 credit facilities we entered into in June 2015 (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 previous credit facilities. As of September 30, 2016 , 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, 2016 December 31, 2015 Interest Rate Derivatives Derivative liabilities $ (6,376 ) $ (5,940 ) Interest Rate Derivatives Non-current derivative liabilities (9,572 ) (2,800 ) 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 three and nine months ended September 30, 2016 and 2015 : Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest Rate Derivatives gain (loss) $ 2,557 $ (10,872 ) $ (13,473 ) $ (46,541 ) Commodity Derivatives Liquefaction Supply Derivatives We have entered into index-based physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the Liquefaction Project . The terms of the physical natural gas supply contracts primarily range from approximately one to seven years and commence upon the satisfaction of certain conditions precedent, including but not limited to the date of first commercial operation of specified Train s of the Liquefaction Project . We recognize our Physical Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Physical Liquefaction Supply Derivatives are reported in earnings. As of September 30, 2016 , we have secured up to approximately 1,982.0 million MMBtu of natural gas feedstock through natural gas supply contracts. The notional natural gas position of our Physical Liquefaction Supply Derivatives was approximately 1,069.0 million MMBtu as of September 30, 2016 . Our Financial Liquefaction Supply 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 Financial Liquefaction Supply Derivatives activities. Natural Gas Derivatives Our Natural Gas Derivatives were executed through over-the-counter contracts which were subject to nominal credit risk as these transactions settled on a daily margin basis with investment grade financial institutions. We were required by these financial institutions to use margin deposits as credit support for our Natural Gas Derivatives activities. As of September 30, 2016 , we did not have any open Natural Gas Derivatives positions or margin deposits at financial institutions. We recognize all commodity derivative instruments, including our Liquefaction Supply Derivatives and our Natural Gas 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, 2016 December 31, 2015 Liquefaction Supply Derivatives (1) Natural Gas Derivatives Total Liquefaction Supply Derivatives Natural Gas Derivatives (2) Total Balance Sheet Location Other current assets $ 1,947 $ — $ 1,947 $ 2,737 $ 29 $ 2,766 Non-current derivative assets 11,247 — 11,247 30,304 — 30,304 Total derivative assets 13,194 — 13,194 33,041 29 33,070 Derivative liabilities (1,083 ) — (1,083 ) (490 ) — (490 ) Non-current derivative liabilities (11 ) — (11 ) (84 ) — (84 ) Total derivative liabilities (1,094 ) — (1,094 ) (574 ) — (574 ) Derivative asset, net $ 12,100 $ — $ 12,100 $ 32,467 $ 29 $ 32,496 (1) Does not include collateral of $1.5 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of September 30, 2016 . (2) Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015 . The following table (in thousands) shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Statements of Operations during the three and nine months ended September 30, 2016 and 2015 : Three Months Ended Nine Months Ended September 30, September 30, Statement of Operations Location 2016 2015 2016 2015 Liquefaction Supply Derivatives gain LNG revenues $ 374 $ — $ 368 $ — Liquefaction Supply Derivatives gain (loss) (1) Cost (cost recovery) of sales (10,416 ) 32,103 (22,680 ) 32,184 Natural Gas Derivatives gain Operating and maintenance expense — 778 150 1,221 (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position. Balance Sheet Presentation Our derivative instruments 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, 2016 Interest Rate Derivatives $ (15,948 ) $ — $ (15,948 ) Liquefaction Supply Derivatives 13,740 (546 ) 13,194 Liquefaction Supply Derivatives (2,803 ) 1,709 (1,094 ) As of December 31, 2015 Interest Rate Derivatives $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives 33,636 (595 ) 33,041 Liquefaction Supply Derivatives (574 ) — (574 ) Natural Gas Derivatives 152 (123 ) 29

Other Non-Current Assets

Other Non-Current Assets	9 Months Ended
	Sep. 30, 2016
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS As of September 30, 2016 and December 31, 2015 , other non-current assets consisted of the following (in thousands): September 30, December 31, 2016 2015 Advances made under EPC and non-EPC contracts $ 13,678 $ 32,049 Advances made to municipalities for water system enhancements 95,551 89,953 Tax-related payments and receivables 3,185 5,535 Information technology service assets 23,186 24,166 Other 44,232 43,115 Total other non-current assets $ 179,832 $ 194,818

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2016
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of September 30, 2016 and December 31, 2015 , accrued liabilities consisted of the following (in thousands): September 30, December 31, 2016 2015 Interest costs and related debt fees $ 140,716 $ 135,336 Liquefaction Project costs 185,961 66,223 Other accrued liabilities 138 — Total accrued liabilities $ 326,815 $ 201,559

Debt

Debt	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Debt	DEBT As of September 30, 2016 and December 31, 2015 , our debt consisted of the following (in thousands): September 30, December 31, 2016 2015 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7,573 and $8,718 $ 2,007,573 $ 2,008,718 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000,000 1,000,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5,844 and $6,392 1,505,844 1,506,392 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000,000 2,000,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000,000 2,000,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500,000 — 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500,000 — 2015 Credit Facilities — 845,000 Unamortized debt issuance costs (1) (182,944 ) (154,551 ) Total long-term debt, net 11,330,473 9,205,559 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) 98,500 15,000 Total debt, net $ 11,428,973 $ 9,220,559 (1) Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015 . 2016 Debt Issuances and Redemptions Senior Notes In June and September 2016, we issued the 2026 Senior Notes and the 2027 Senior Notes , respectively, for aggregate principal amounts of $1.5 billion each. Net proceeds of the offerings of the 2026 Senior Notes and 2027 Senior Notes were approximately $1.3 billion and $1.4 billion , respectively, after deducting commissions, fees and expenses and incremental interest required under the respective senior notes during construction. The net proceeds were used to prepay a portion (for the 2026 Senior Notes ) or all (for the 2027 Senior Notes ) outstanding borrowings and terminate commitments under the 2015 Credit Facilities , resulting in a write-off of debt issuance costs associated with the 2015 Credit Facilities of $25.8 million and $51.8 million during the three and nine months ended September 30, 2016 , respectively. The remaining proceeds from the 2027 Senior Notes are being used to pay a portion of the capital costs in connection with the construction of Trains 1 through 5 of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2015 Credit Facilities . The 2026 Senior Notes and 2027 Senior Notes accrue interest at fixed rates of 5.875% and 5.00% , respectively, and interest is payable semi-annually in arrears. The terms of the 2026 Senior Notes and 2027 Senior Notes are governed by the same common indenture as our other senior notes, which contains customary terms and events of default, covenants and redemption terms. In connection with the issuance of the 2026 Senior Notes and the 2027 Senior Notes , we entered into registration rights agreements (the “Registration Rights Agreements”) . Under the terms of the Registration Rights Agreements , we have agreed, and any future guarantors will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to offers to exchange any and all of the 2026 Senior Notes and 2027 Senior Notes for like aggregate principal amounts of our debt securities with terms identical in all material respects to the respective senior notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), within 360 days after June 14, 2016 and September 23, 2016, respectively. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective shelf registration statements relating to resales of the 2026 Senior Notes and the 2027 Senior Notes . We will be obligated to pay additional interest on these senior notes if we fail to comply with our obligation to register them within the specified time period. Credit Facilities Below is a summary of our credit facilities outstanding as of September 30, 2016 (in thousands): 2015 Credit Facilities Working Capital Facility Original facility size $ 4,600,000 $ 1,200,000 Outstanding balance — 98,500 Commitments prepaid or terminated 2,643,867 — Letters of credit issued — 337,044 Available commitment $ 1,956,133 $ 764,456 Interest rate LIBOR plus 1.30% - 1.75% or base rate plus 1.75% LIBOR plus 1.75% or base rate plus 0.75% Maturity date Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date December 31, 2020, with various terms for underlying loans Interest Expense Total interest expense consisted of the following (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Total interest cost $ 168,228 $ 141,068 $ 469,546 $ 387,963 Capitalized interest (102,289 ) (129,116 ) (370,343 ) (356,702 ) Total interest expense, net $ 65,939 $ 11,952 $ 99,203 $ 31,261 Fair Value Disclosures The following table (in thousands) shows the carrying amount and estimated fair value of our debt: September 30, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior Notes, net of premium (1) $ 11,513,417 $ 12,281,145 $ 8,515,110 $ 7,469,718 Credit facilities (2) 98,500 98,500 860,000 860,000 (1) Includes 2021 Senior Notes , net of premium; 2022 Senior Notes ; 2023 Senior Notes , net of premium; 2024 Senior Notes ; 2025 Senior Notes ; 2026 Senior Notes ; and 2027 Senior Notes (collectively, the “Senior Notes”) . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments. (2) Includes 2015 Credit Facilities and Working Capital Facility . 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.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Statements of Operations for the three and nine months ended September 30, 2016 and 2015 (in thousands): Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 LNG revenues—affiliate Cheniere Marketing Master SPA $ 16,236 $ — $ 16,236 $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 1,815 — 2,460 — Fees under the Pre-commercial LNG Marketing Agreement 1,430 — 1,430 — Total cost of sales—affiliate 3,245 — 3,890 — Operating and maintenance expense—affiliate TUA 18,522 — 28,764 — Natural Gas Transportation Agreement 16,660 — 24,344 — Services Agreements 8,051 93 12,530 221 LNG Site Sublease Agreement 235 235 592 235 Total operating and maintenance expense—affiliate 43,468 328 66,230 456 Terminal use agreement maintenance expense—affiliate TUA — 130 208 308 Development expense—affiliate Services Agreements 87 152 369 562 LNG Site Sublease Agreement — — 115 — Total development expense—affiliate 87 152 484 562 General and administrative expense—affiliate Services Agreements 18,942 18,938 51,824 58,048 LNG Site Sublease Agreement — — — 241 Other agreements — — — 15 Total general and administrative expense—affiliate 18,942 18,938 51,824 58,304 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 (the “TUA Fees”) , 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 the TURA pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees 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 TUA Fees 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 TUA Fees payable by us will increase by the amount that Cheniere Investments’ percentage decreases. In May 2016, upon substantial completion of Train 1 of the Liquefaction Project , Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was reduced from 100% to 75% and our percentage of all TUA Fees payable to SPLNG was increased from zero to 25% in accordance with the TURA . Subsequently, in September 2016, upon substantial completion of Train 2 of the Liquefaction Project , Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was further reduced from 75% to 50% and our percentage of all TUA Fees payable to SPLNG was further increased from 25% to 50% in accordance with the TURA . Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA . Cargo loading fees incurred under this agreement are recorded as cost of sales—affiliate, except for the portion related to commissioning activities which is capitalized as LNG terminal construction-in-process. 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. We are required to reimburse SPLNG for a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal, which is recorded as terminal use agreement maintenance expense on our Statements of Operations. 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. Cheniere Marketing SPA Cheniere Marketing has entered into an SPA with us to purchase, at Cheniere Marketing’s option, any 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 . Cheniere Marketing Master SPA In May 2015, we entered into an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. Commissioning Confirmation In May 2015, under the Cheniere Marketing Master SPA, we executed a confirmation 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, one of our SPA customers. We pay a fee to Cheniere Marketing for marketing and transportation, which is based on volume sold under this agreement. Natural Gas Transportation Agreement To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, we have entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of Cheniere Partners, and third-party pipeline companies. Services Agreements 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. 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. The non-reimbursement amounts incurred under this agreement are recorded in general and administrative expense—affiliate. 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. Cheniere Investments Information Technology Services Agreement Cheniere Investments has entered into an information technology services agreement with Cheniere, pursuant to which Cheniere Investment’s subsidiaries, including us, receive certain information technology services. On a quarterly basis, the various entities receiving the benefit are invoiced by Cheniere according to the cost allocation percentages set forth in the agreement. In addition, Cheniere is entitled to reimbursement for all costs incurred by Cheniere that are necessary to perform the services under the agreement. 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 aggregate annual sublease payment is $0.9 million , which was increased from $0.5 million during 2015. The initial terms of the subleases expire on December 31, 2034, with options to renew for multiple 10 -year extensions with similar terms as the initial terms. The annual sublease payments will be adjusted for inflation every 5 years based on a consumer price index, as defined in the sublease agreements. 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 zero and $252.8 million of assets for the three and nine months ended September 30, 2016 , respectively, and zero and $80.5 million of assets for the three and nine months ended September 30, 2015 , respectively, which have been recorded as non-cash distributions to affiliates. 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 transferred to CTPL following construction. Upon completion of certain modifications during the third quarter of 2015, we conveyed to CTPL $10.1 million of assets under this agreement. Contract for Sale and Purchase of Natural Gas and LNG We have entered into an agreement with SPLNG that allows us to sell and purchase natural gas and LNG with SPLNG. Natural gas and LNG purchased under this agreement are recorded as inventory, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. 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.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2016
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, 2016 2015 Cash paid during the period for interest, net of amounts capitalized $ 60,506 $ 13,471 Non-cash distributions to affiliates for conveyance of assets 252,802 90,645 Other non-cash distribution to affiliates — 149 Non-cash conveyance of assets to non-affiliate — 13,169 The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $295.6 million and $358.3 million , as of September 30, 2016 and 2015 , respectively.

Recent Accounting Standards

Recent Accounting Standards	9 Months Ended
	Sep. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards	RECENT ACCOUNTING STANDARDS The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of September 30, 2016 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard amends existing revenue recognition guidance and requires an entity to 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 may be early adopted beginning January 1, 2017, and may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern This standard 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. Early adoption is permitted. December 31, 2016 The adoption of this guidance is not expected to have an impact on our Financial Statements or related disclosures. Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to 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 may be early adopted and must be adopted prospectively. January 1, 2017 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. Additionally, the following table provides a brief description of a recent accounting standard that was adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements These standards require 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. Debt issuance costs incurred in connection with line of credit arrangements may be presented as an asset and subsequently amortized ratably over the term of the line of credit arrangement. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. January 1, 2016 Upon adoption of these standards, the balance of debt, net was reduced by the balance of debt issuance costs, net, except for the balance related to line of credit arrangements, on our Balance Sheets. See Note 9—Debt for additional disclosures.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with 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, operating results or cash flows. In 2016, we started production at our natural gas liquefaction facilities at the Sabine Pass LNG terminal located in Cameron Parish, Louisiana (the “Liquefaction Project”) . As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project , and other related costs to convert natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities.
Income Tax, 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.

Restricted Cash (Tables)

Restricted Cash (Tables)	9 Months Ended
	Sep. 30, 2016
Cash and Cash Equivalents [Abstract]
Schedule of Restricted Cash	As of September 30, 2016 and December 31, 2015 , restricted cash consisted of the following (in thousands): September 30, December 31, 2016 2015 Current restricted cash Liquefaction Project $ 325,630 $ 189,260

Accounts and Other Receivables

Accounts and Other Receivables (Tables)	9 Months Ended
	Sep. 30, 2016
Receivables [Abstract]
Schedule of Accounts and Other Receivables	As of September 30, 2016 and December 31, 2015 , accounts and other receivables consisted of the following (in thousands): September 30, December 31, 2016 2015 Trade receivable $ 38,432 $ — Interest receivable 53 7 Other accounts receivable 12,481 570 Total accounts and other receivables $ 50,966 $ 577

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2016
Inventory Disclosure [Abstract]
Schedule of Inventory	As of September 30, 2016 and December 31, 2015 , inventory consisted of the following (in thousands): September 30, December 31, 2016 2015 Natural gas $ 4,181 $ 5,724 LNG 25,280 — Materials and other 22,254 18 Total inventory $ 51,715 $ 5,742

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2016
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, 2016 2015 LNG terminal costs LNG terminal $ 5,264,538 $ 42,220 LNG terminal construction-in-process 6,254,085 9,795,309 Accumulated depreciation (32,493 ) (789 ) Total LNG terminal costs, net 11,486,130 9,836,740 Fixed assets Furniture and fixtures 1,446 1,154 Computer software 4,144 3,782 Machinery and equipment 405 339 Vehicles 2,419 1,405 Other 720 390 Accumulated depreciation (3,985 ) (2,403 ) Total fixed assets, net 5,149 4,667 Property, plant and equipment, net $ 11,491,279 $ 9,841,407

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
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 the derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2016 and December 31, 2015 , 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, 2016 December 31, 2015 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 Interest Rate Derivatives liability $ — $ (15,948 ) $ — $ (15,948 ) $ — $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives asset (liability) (105 ) (275 ) 12,480 12,100 — (25 ) 32,492 32,467 Natural Gas Derivatives asset — — — — — 29 — 29
Fair Value Inputs, Assets, Quantitative Information	The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2016 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $12,480 Income Approach Basis Spread $(0.35) - $(0.03)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The following table (in thousands) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2016 and 2015 : Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Balance, beginning of period $ 22,434 $ 440 $ 32,492 $ 342 Realized and mark-to-market losses: Included in cost of sales (1) (10,567 ) 32,177 (20,482 ) 32,204 Purchases and settlements: Purchases 968 — 968 — Settlements (1) (308 ) (71 ) (741 ) — Transfers out of Level 3 (2) (47 ) — 243 — Balance, end of period $ 12,480 $ 32,546 $ 12,480 $ 32,546 Change in unrealized gains relating to instruments still held at end of period $ (10,567 ) $ — $ (19,763 ) $ — (1) Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the nine months ended September 30, 2016 . (2) Transferred to Level 2 as a result of observable market for the underlying natural gas supply contracts.
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, 2016 Interest Rate Derivatives $ (15,948 ) $ — $ (15,948 ) Liquefaction Supply Derivatives 13,740 (546 ) 13,194 Liquefaction Supply Derivatives (2,803 ) 1,709 (1,094 ) As of December 31, 2015 Interest Rate Derivatives $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives 33,636 (595 ) 33,041 Liquefaction Supply Derivatives (574 ) — (574 ) Natural Gas Derivatives 152 (123 ) 29
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions	As of September 30, 2016 , 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
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, 2016 December 31, 2015 Interest Rate Derivatives Derivative liabilities $ (6,376 ) $ (5,940 ) Interest Rate Derivatives Non-current derivative liabilities (9,572 ) (2,800 )
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 three and nine months ended September 30, 2016 and 2015 : Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest Rate Derivatives gain (loss) $ 2,557 $ (10,872 ) $ (13,473 ) $ (46,541 )
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, 2016 December 31, 2015 Liquefaction Supply Derivatives (1) Natural Gas Derivatives Total Liquefaction Supply Derivatives Natural Gas Derivatives (2) Total Balance Sheet Location Other current assets $ 1,947 $ — $ 1,947 $ 2,737 $ 29 $ 2,766 Non-current derivative assets 11,247 — 11,247 30,304 — 30,304 Total derivative assets 13,194 — 13,194 33,041 29 33,070 Derivative liabilities (1,083 ) — (1,083 ) (490 ) — (490 ) Non-current derivative liabilities (11 ) — (11 ) (84 ) — (84 ) Total derivative liabilities (1,094 ) — (1,094 ) (574 ) — (574 ) Derivative asset, net $ 12,100 $ — $ 12,100 $ 32,467 $ 29 $ 32,496 (1) Does not include collateral of $1.5 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of September 30, 2016 . (2) Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015 .
Derivative Instruments, Gain (Loss)	The following table (in thousands) shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Statements of Operations during the three and nine months ended September 30, 2016 and 2015 : Three Months Ended Nine Months Ended September 30, September 30, Statement of Operations Location 2016 2015 2016 2015 Liquefaction Supply Derivatives gain LNG revenues $ 374 $ — $ 368 $ — Liquefaction Supply Derivatives gain (loss) (1) Cost (cost recovery) of sales (10,416 ) 32,103 (22,680 ) 32,184 Natural Gas Derivatives gain Operating and maintenance expense — 778 150 1,221 (1) Does not include the realized value associated with derivative instruments that settle through physical delivery.

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	9 Months Ended
	Sep. 30, 2016
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	As of September 30, 2016 and December 31, 2015 , other non-current assets consisted of the following (in thousands): September 30, December 31, 2016 2015 Advances made under EPC and non-EPC contracts $ 13,678 $ 32,049 Advances made to municipalities for water system enhancements 95,551 89,953 Tax-related payments and receivables 3,185 5,535 Information technology service assets 23,186 24,166 Other 44,232 43,115 Total other non-current assets $ 179,832 $ 194,818

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2016
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of September 30, 2016 and December 31, 2015 , accrued liabilities consisted of the following (in thousands): September 30, December 31, 2016 2015 Interest costs and related debt fees $ 140,716 $ 135,336 Liquefaction Project costs 185,961 66,223 Other accrued liabilities 138 — Total accrued liabilities $ 326,815 $ 201,559

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of September 30, 2016 and December 31, 2015 , our debt consisted of the following (in thousands): September 30, December 31, 2016 2015 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7,573 and $8,718 $ 2,007,573 $ 2,008,718 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000,000 1,000,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5,844 and $6,392 1,505,844 1,506,392 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000,000 2,000,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000,000 2,000,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500,000 — 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500,000 — 2015 Credit Facilities — 845,000 Unamortized debt issuance costs (1) (182,944 ) (154,551 ) Total long-term debt, net 11,330,473 9,205,559 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) 98,500 15,000 Total debt, net $ 11,428,973 $ 9,220,559 (1) Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015 .
Schedule of Line of Credit Facilities	Below is a summary of our credit facilities outstanding as of September 30, 2016 (in thousands): 2015 Credit Facilities Working Capital Facility Original facility size $ 4,600,000 $ 1,200,000 Outstanding balance — 98,500 Commitments prepaid or terminated 2,643,867 — Letters of credit issued — 337,044 Available commitment $ 1,956,133 $ 764,456 Interest rate LIBOR plus 1.30% - 1.75% or base rate plus 1.75% LIBOR plus 1.75% or base rate plus 0.75% Maturity date Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date December 31, 2020, with various terms for underlying loans
Interest Income and Interest Expense Disclosure	Total interest expense consisted of the following (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Total interest cost $ 168,228 $ 141,068 $ 469,546 $ 387,963 Capitalized interest (102,289 ) (129,116 ) (370,343 ) (356,702 ) Total interest expense, net $ 65,939 $ 11,952 $ 99,203 $ 31,261
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 debt: September 30, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior Notes, net of premium (1) $ 11,513,417 $ 12,281,145 $ 8,515,110 $ 7,469,718 Credit facilities (2) 98,500 98,500 860,000 860,000 (1) Includes 2021 Senior Notes , net of premium; 2022 Senior Notes ; 2023 Senior Notes , net of premium; 2024 Senior Notes ; 2025 Senior Notes ; 2026 Senior Notes ; and 2027 Senior Notes (collectively, the “Senior Notes”) . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments. (2) Includes 2015 Credit Facilities and Working Capital Facility . 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.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Operations for the three and nine months ended September 30, 2016 and 2015 (in thousands): Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 LNG revenues—affiliate Cheniere Marketing Master SPA $ 16,236 $ — $ 16,236 $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 1,815 — 2,460 — Fees under the Pre-commercial LNG Marketing Agreement 1,430 — 1,430 — Total cost of sales—affiliate 3,245 — 3,890 — Operating and maintenance expense—affiliate TUA 18,522 — 28,764 — Natural Gas Transportation Agreement 16,660 — 24,344 — Services Agreements 8,051 93 12,530 221 LNG Site Sublease Agreement 235 235 592 235 Total operating and maintenance expense—affiliate 43,468 328 66,230 456 Terminal use agreement maintenance expense—affiliate TUA — 130 208 308 Development expense—affiliate Services Agreements 87 152 369 562 LNG Site Sublease Agreement — — 115 — Total development expense—affiliate 87 152 484 562 General and administrative expense—affiliate Services Agreements 18,942 18,938 51,824 58,048 LNG Site Sublease Agreement — — — 241 Other agreements — — — 15 Total general and administrative expense—affiliate 18,942 18,938 51,824 58,304

Supplemental Cash Flow Inform28

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2016
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, 2016 2015 Cash paid during the period for interest, net of amounts capitalized $ 60,506 $ 13,471 Non-cash distributions to affiliates for conveyance of assets 252,802 90,645 Other non-cash distribution to affiliates — 149 Non-cash conveyance of assets to non-affiliate — 13,169

Recent Accounting Standards (Ta

Recent Accounting Standards (Tables)	9 Months Ended
	Sep. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards, Not Yet Adopted	The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of September 30, 2016 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard amends existing revenue recognition guidance and requires an entity to 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 may be early adopted beginning January 1, 2017, and may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern This standard 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. Early adoption is permitted. December 31, 2016 The adoption of this guidance is not expected to have an impact on our Financial Statements or related disclosures. Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to 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 may be early adopted and must be adopted prospectively. January 1, 2017 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.
Recent Accounting Standards, Adopted	Additionally, the following table provides a brief description of a recent accounting standard that was adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements These standards require 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. Debt issuance costs incurred in connection with line of credit arrangements may be presented as an asset and subsequently amortized ratably over the term of the line of credit arrangement. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. January 1, 2016 Upon adoption of these standards, the balance of debt, net was reduced by the balance of debt issuance costs, net, except for the balance related to line of credit arrangements, on our Balance Sheets. See Note 9—Debt for additional disclosures.

Basis of Presentation (Details)

Basis of Presentation (Details) - customer	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016
SPA Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Number Of Significant Customers		1
Customer Concentration Risk [Member] | LNG Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	70.00%	77.00%

Restricted Cash (Details)

Restricted Cash (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	$ 325,630	$ 189,260
Liquefaction Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	$ 325,630	$ 189,260

Accounts and Other Receivable32

Accounts and Other Receivables (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Receivables [Abstract]
Trade receivable	$ 38,432	$ 0
Interest receivable	53	7
Other accounts receivable	12,481	570
Total accounts and other receivables	$ 50,966	$ 577

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Inventory [Line Items]
Inventory	$ 51,715	$ 5,742
Natural gas [Member]
Inventory [Line Items]
Inventory	4,181	5,724
LNG [Member]
Inventory [Line Items]
Inventory	25,280	0
Materials and other [Member]
Inventory [Line Items]
Inventory	$ 22,254	$ 18

Property, Plant and Equipment34

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 11,491,279	$ 11,491,279	$ 9,841,407
Property, plant and equipment, reduction for testing costs recovered	58,700	201,000
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(32,493)	(32,493)	(789)
Property, plant and equipment, net	11,486,130	11,486,130	9,836,740
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	5,264,538	5,264,538	42,220
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,254,085	6,254,085	9,795,309
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(3,985)	(3,985)	(2,403)
Property, plant and equipment, net	5,149	5,149	4,667
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,446	1,446	1,154
Computer software [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	4,144	4,144	3,782
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	405	405	339
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,419	2,419	1,405
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 720	$ 720	$ 390

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) MMBTU in Millions, $ in Millions	1 Months Ended	9 Months Ended
	Mar. 31, 2015USD ($)	Sep. 30, 2016MMBTU
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Energy Units Secured Through Long-Term Purchase Agreements | MMBTU		1,982
Previous Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease | $	$ 1,800
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net | $	$ 34.7
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount | MMBTU		1,069
Liquefaction Supply Derivatives [Member] | Minimum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract		1 year
Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract		7 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (15,948)	$ (8,740)
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
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	(15,948)	(8,740)
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
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	12,100	32,467
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	(105)	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	(275)	(25)
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	12,480	32,492
Natural Gas Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	29
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
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	0	29
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

Derivative Instruments - Fair37

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Liquefaction Supply Derivatives [Member] - USD ($)	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 12,100,000	$ 32,467,000
Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 12,480,000	$ 32,492,000
Valuation Technique	Income Approach
Significant Unobservable Input	Basis Spread
Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ (0.350)
Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ (0.030)

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Liquefaction Supply Derivatives [Member] - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ 22,434	$ 440	$ 32,492	$ 342
Realized and mark-to-market losses
Included in cost of sales	[1]	(10,567)	32,177	(20,482)	32,204
Purchases and settlements:
Purchases		968	0	968	0
Settlements	[1]	(308)	(71)	(741)	0
Transfers out of Level 3	[2]	(47)	0	243	0
Balance, end of period		12,480	32,546	12,480	32,546
Change in unrealized gains relating to instruments still held at end of period		$ (10,567)	$ 0	(19,763)	$ 0
Decrease in Fair Value Realized and Capitalized During Period				$ 700
[1]	Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the nine months ended September 30, 2016
[2]	Transferred to Level 2 as a result of observable market for the underlying natural gas supply contracts.

Derivative Instruments - Sche39

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - Interest Rate Derivatives [Member] $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 20
Effective Date	Aug. 14, 2012
Maturity Date	Jul. 31, 2019
Weighted Average Fixed Interest Rate Paid	1.98%
Variable Interest Rate Received	One-month LIBOR
Maximum [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 628.8

Derivative Instruments - Fair40

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Thousands	Sep. 30, 2016		Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Non-current derivative assets	$ 11,247		$ 30,304
Derivative liabilities	(7,459)		(6,430)
Non-current derivative liabilities	(9,583)		(2,884)
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(6,376)		(5,940)
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	(9,572)		(2,800)
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	13,194		33,070
Total derivative liabilities	(1,094)		(574)
Derivative asset, net	12,100		32,496
Commodity Contract [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	1,947		2,766
Commodity Contract [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	11,247		30,304
Commodity Contract [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(1,083)		(490)
Commodity Contract [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	(11)		(84)
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	13,194	[1]	33,041
Total derivative liabilities	(1,094)	[1]	(574)
Derivative asset, net	12,100	[1]	32,467
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	1,947	[1]	2,737
Derivative, Collateral, Right to Reclaim Cash	1,500
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	11,247	[1]	30,304
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(1,083)	[1]	(490)
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	(11)	[1]	(84)
Natural Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	0		29	[2]
Total derivative liabilities	0		0	[2]
Derivative asset, net	0		29	[2]
Natural Gas Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	0		29	[2]
Derivative, Collateral, Right to Reclaim Cash			400
Natural Gas Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	0		0	[2]
Natural Gas Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0		0	[2]
Natural Gas Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	$ 0		$ 0	[2]
[1]	Does not include collateral of $1.5 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of September 30, 2016.
[2]	Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Thousands		1 Months Ended	3 Months Ended		9 Months Ended
		Mar. 31, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Interest Rate Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ (34,700)
Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net			$ 2,557	$ (10,872)	$ (13,473)	$ (46,541)
Liquefaction Supply Derivatives [Member] | LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net			374	0	368	0
Liquefaction Supply Derivatives [Member] | Cost (cost recovery) of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]		(10,416)	32,103	(22,680)	32,184
Natural Gas Derivatives [Member] | Operating and maintenance expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net			$ 0	$ 778	$ 150	$ 1,221
[1]	Does not include the realized value associated with derivative instruments that settle through physical delivery.

Derivative Instruments - Deri42

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Interest Rate Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	$ (15,948)	$ (8,740)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	0	0
Net Amounts Presented in our Balance Sheets	(15,948)	(8,740)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	13,740	33,636
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(546)	(595)
Net Amounts Presented in our Balance Sheets	13,194	33,041
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(2,803)	(574)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	1,709	0
Net Amounts Presented in our Balance Sheets	$ (1,094)	(574)
Natural Gas Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		152
Derivative Asset, Gross Amounts Offset in the Balance Sheets		(123)
Net Amounts Presented in our Balance Sheets		$ 29

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Other Assets, Noncurrent [Abstract]
Advances made under EPC and non-EPC contracts	$ 13,678	$ 32,049
Advances made to municipalities for water system enhancements	95,551	89,953
Tax-related payments and receivables	3,185	5,535
Information technology service assets	23,186	24,166
Other	44,232	43,115
Other non-current assets	$ 179,832	$ 194,818

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 140,716	$ 135,336
Liquefaction Project costs	185,961	66,223
Other accrued liabilities	138	0
Total accrued liabilities	$ 326,815	$ 201,559

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($)		Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Net		$ 11,330,473,000	$ 9,205,559,000
Unamortized Debt Issuance Costs, Noncurrent	[1]	(182,944,000)	(154,551,000)
Current Debt, Working Capital Facility		98,500,000	15,000,000
Total Debt, Net		11,428,973,000	9,220,559,000
Accounting Standards Update 2015-03 [Member] | Debt Issuance Costs, Net [Member]
Debt Instrument [Line Items]
Unamortized Debt Issuance Costs, Noncurrent			(154,551,000)
Accounting Standards Update 2015-03 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Unamortized Debt Issuance Costs, Noncurrent			154,551,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 2,007,573,000	2,008,718,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Debt Instrument, Unamortized Premium		$ 7,573,000	8,718,000
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 1,000,000,000	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 1,505,844,000	1,506,392,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Debt Instrument, Unamortized Premium		$ 5,844,000	6,392,000
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 2,000,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 2,000,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 1,500,000,000	0
Debt Instrument, Interest Rate, Stated Percentage		5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 1,500,000,000	0
Debt Instrument, Interest Rate, Stated Percentage		5.00%
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Net		$ 0	$ 845,000,000
Working Capital Facility [Member]
Debt Instrument [Line Items]
Current Debt, Working Capital Facility		98,500,000
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,200,000,000
[1]	Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015.

Debt - Debt Issuances and Redem

Debt - Debt Issuances and Redemptions (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Debt Instrument [Line Items]
Loss on Extinguishment of Debt			$ 25,765	$ 0	$ 52,070	$ 96,273
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,500,000
Proceeds from Issuance of Long-term Debt		$ 1,300,000
Debt Instrument, Interest Rate, Stated Percentage	5.875%		5.875%		5.875%
Debt Instrument Registration Period					360 days
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,500,000		$ 1,500,000		$ 1,500,000
Proceeds from Issuance of Long-term Debt	$ 1,400,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%		5.00%		5.00%
Debt Instrument Registration Period					360 days
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Loss on Extinguishment of Debt			$ 25,800		$ 51,800

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Outstanding balance	$ 11,330,473	$ 9,205,559
Outstanding Balance, Current	98,500	15,000
2015 Credit Facilities [Member]
Line of Credit Facility [Line Items]
Original facility size	4,600,000
Outstanding balance	0	$ 845,000
Commitments prepaid or terminated	2,643,867
Letters of credit issued	0
Available commitment	$ 1,956,133
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Debt Instrument, Maturity Date, Description	Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date
2015 Credit Facilities [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
2015 Credit Facilities [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.30%
2015 Credit Facilities [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 1,200,000
Outstanding Balance, Current	98,500
Commitments prepaid or terminated	0
Letters of credit issued	337,044
Available commitment	$ 764,456
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Debt Instrument, Maturity Date, Description	December 31, 2020, with various terms for underlying loans
Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
Working Capital Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.75%

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Debt Disclosure [Abstract]
Total interest cost	$ 168,228	$ 141,068	$ 469,546	$ 387,963
Capitalized interest	(102,289)	(129,116)	(370,343)	(356,702)
Total interest expense, net	$ 65,939	$ 11,952	$ 99,203	$ 31,261

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Thousands		Sep. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 11,428,973	$ 9,220,559
Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	11,513,417	8,515,110
Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	12,281,145	7,469,718
Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	98,500	860,000
Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Credit Facilities, Estimated Fair Value	[2]	$ 98,500	$ 860,000
[1]	Includes 2021 Senior Notes, net of premium; 2022 Senior Notes; 2023 Senior Notes, net of premium; 2024 Senior Notes; 2025 Senior Notes; 2026 Senior Notes; and 2027 Senior Notes (collectively, the “Senior Notes”). The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments.
[2]	Includes 2015 Credit Facilities and Working Capital Facility. 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.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 16,236	$ 0	$ 16,236	$ 0
Cost of sales—affiliate	3,245	0	3,890	0
Operating and maintenance expense—affiliate	43,468	328	66,230	456
Terminal use agreement maintenance expense—affiliate	0	130	208	308
Development expense—affiliate	87	152	484	562
General and administrative expense—affiliate	18,942	18,938	51,824	58,304
Cheniere Marketing Master SPA [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	16,236	0	16,236	0
Cargo loading fees under the Terminal Use Rights Assignment and Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	1,815	0	2,460	0
Fees under Pre-commercial LNG Marketing Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	1,430	0	1,430	0
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	18,522	0	28,764	0
Terminal use agreement maintenance expense—affiliate	0	130	208	308
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	16,660	0	24,344	0
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	8,051	93	12,530	221
Development expense—affiliate	87	152	369	562
General and administrative expense—affiliate	18,942	18,938	51,824	58,048
LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	235	235	592	235
Development expense—affiliate	0	0	115	0
General and administrative expense—affiliate	0	0	0	241
Other agreements [Member]
Related Party Transaction [Line Items]
General and administrative expense—affiliate	$ 0	$ 0	$ 0	$ 15

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	Aug. 31, 2016	Apr. 30, 2016	Sep. 30, 2016USD ($)mi	May 31, 2016	Sep. 30, 2016USD ($)mi	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)bcf / dtrainsmi$ / MMBTU	Sep. 30, 2015USD ($)
Terminal Use Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d							2
Related Party Transaction, Committed Annual Fee							$ 250,000,000
Related Party Agreement Term							20 years
Related Party Transaction, Percentage Of Committed Monthly Payment	25.00%	0.00%	50.00%	25.00%
Portion of Storage Capacity Reserved							41.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	75.00%	100.00%	50.00%	75.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment							100.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment							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%
Incremental LNG Volume, Purchase Price | $ / MMBTU							3
Commissioning Agreement [Member] | Cheniere Marketing [Member]
Related Party Transaction [Line Items]
Number of Liquefaction LNG Trains Subject To In Agreement | trains							4
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%
Related Party Transaction, Committed Monthly Fee			$ 83,333		$ 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%
Related Party Transaction, Committed Monthly Fee			$ 541,667		541,667		$ 541,667
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment							$ 900,000	$ 500,000
Term of available extension							10 years
Review Period for Inflation Adjustment							5 years
Cooperation Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement					$ 0	$ 0	$ 252,800,000	$ 80,500,000
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		94		94
Tax Sharing Agreement [Member] | Cheniere [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net							$ 0

Supplemental Cash Flow Inform52

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 60,506	$ 13,471
Non-cash distributions to affiliates for conveyance of assets	252,802	90,645
Other non-cash distribution to affiliates	0	149
Non-cash conveyance of assets to non-affiliate	0	13,169
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$ 295,600	$ 358,300