Sabine Pass Liquefaction 10-Q 8 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2017shares
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	Jun. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding	0

Balance Sheets

Balance Sheets - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 0	$ 0
Restricted cash	579	358
Accounts and other receivables	138	90
Accounts receivable—affiliate	43	100
Advances to affiliate	33	26
Inventory	83	89
Other current assets	29	25
Other current assets—affiliate	16	10
Total current assets	921	698
Non-current restricted cash	698	0
Property, plant and equipment, net	12,668	11,875
Debt issuance costs, net	21	58
Non-current derivative assets	32	67
Other non-current assets, net	173	185
Total assets	14,513	12,883
Current liabilities
Accounts payable	39	23
Accrued liabilities	455	407
Current debt	0	224
Due to affiliates	44	33
Deferred revenue	38	46
Derivative liabilities	2	11
Total current liabilities	578	744
Long-term debt, net	13,465	11,649
Non-current derivative liabilities	1	2
Other non-current liabilities—affiliate	0	2
Member’s equity	469	486
Total liabilities and member’s equity	$ 14,513	$ 12,883

Statements of Operations

Statements of Operations - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenues
LNG revenues	$ 503	$ 85	$ 995	$ 85
LNG revenues—affiliate	422	0	753	0
Total revenues	925	85	1,748	85
Operating costs and expenses
Cost of sales (excluding depreciation and amortization expense shown separately below)	578	52	1,088	56
Cost of sales—affiliate	6	1	10	1
Operating and maintenance expense	68	10	107	15
Operating and maintenance expense—affiliate	83	22	142	23
Development expense	1	0	1	0
General and administrative expense	0	3	2	4
General and administrative expense—affiliate	17	16	34	33
Depreciation and amortization expense	67	10	114	12
Total operating costs and expenses	820	114	1,498	144
Income (loss) from operations	105	(29)	250	(59)
Other income (expense)
Interest expense, net of capitalized interest	(127)	(27)	(232)	(33)
Loss on early extinguishment of debt	0	(26)	(42)	(26)
Derivative loss, net	0	(5)	(2)	(16)
Other income	2	0	2	0
Total other expense	(125)	(58)	(274)	(75)
Net loss	$ (20)	$ (87)	$ (24)	$ (134)

Statement of Member's Equity

Statement of Member's Equity - 6 months ended Jun. 30, 2017 - USD ($) $ in Millions	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2016	$ 486	$ 486
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	7	7
Net loss	(24)	(24)
Member's equity, end of period at Jun. 30, 2017	$ 469	$ 469

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash flows from operating activities
Net loss	$ (24)	$ (134)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization expense	114	12
Amortization of debt issuance costs, deferred commitment fees, premium and discount	9	2
Loss on early extinguishment of debt	42	26
Total losses on derivatives, net	42	28
Net cash used for settlement of derivative instruments	(14)	(3)
Changes in operating assets and liabilities:
Accounts and other receivables	(47)	(71)
Accounts receivable—affiliate	57	1
Advances to affiliate	(24)	0
Inventory	13	(22)
Accounts payable and accrued liabilities	66	45
Due to affiliates	11	(1)
Deferred revenue	(8)	0
Other, net	(9)	(8)
Other, net—affiliate	(7)	(5)
Net cash provided by (used in) operating activities	221	(130)
Cash flows from investing activities
Property, plant and equipment, net	(891)	(1,216)
Other	0	(33)
Net cash used in investing activities	(891)	(1,249)
Cash flows from financing activities
Proceeds from issuances of debt	2,314	2,915
Repayments of debt	(703)	(1,442)
Debt issuance and deferred financing costs	(29)	(21)
Capital contributions from Cheniere Partners	7	1
Net cash provided by financing activities	1,589	1,453
Net increase in cash, cash equivalents and restricted cash	919	74
Cash, cash equivalents and restricted cash—beginning of period	358	189
Cash, cash equivalents and restricted cash—end of period	$ 1,277	$ 263

Statements of Cash Flows - Bala

Statements of Cash Flows - Balances per Balance Sheets - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2015
Balances per Balance Sheets:
Cash and cash equivalents	$ 0	$ 0
Restricted cash	579	358
Non-current restricted cash	698	0
Total cash, cash equivalents and restricted cash	$ 1,277	$ 358	$ 263	$ 189

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	6 Months Ended
	Jun. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We were formed by Cheniere Partners to own, develop and operate natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities owned and operated by SPLNG. Our Liquefaction Project is being developed and constructed at the Sabine Pass LNG terminal, which is located on the Sabine-Neches Waterway less than four miles from the Gulf Coast. We plan to construct up to six Trains, which are in various stages of development, construction and operations. Trains 1 through 3 are operational, Train 4 is undergoing commissioning, Train 5 is under construction and Train 6 is being commercialized and has all necessary regulatory approvals in place. In the second quarter of 2016, we started production at the Liquefaction Project and began recognizing LNG revenues, which include fees that are received pursuant to our long-term SPAs and other related revenues. 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 and should be read in conjunction with the Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2016 . In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows. Results of operations for the three and six months ended June 30, 2017 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2017 . 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

Restricted Cash	6 Months Ended
	Jun. 30, 2017
Restricted Cash [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 June 30, 2017 and December 31, 2016 , restricted cash consisted of the following (in millions): June 30, December 31, 2017 2016 Current restricted cash Liquefaction Project $ 579 $ 358 Non-current restricted cash Liquefaction Project 698 —

Accounts and Other Receivables

Accounts and Other Receivables	6 Months Ended
	Jun. 30, 2017
Receivables [Abstract]
Accounts and Other Receivables	ACCOUNTS AND OTHER RECEIVABLES As of June 30, 2017 and December 31, 2016 , accounts and other receivables consisted of the following (in millions): June 30, December 31, 2017 2016 Trade receivable $ 123 $ 88 Other accounts receivable 15 2 Total accounts and other receivables $ 138 $ 90 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.

Inventory

Inventory	6 Months Ended
	Jun. 30, 2017
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of June 30, 2017 and December 31, 2016 , inventory consisted of the following (in millions): June 30, December 31, 2017 2016 Natural gas $ 17 $ 15 LNG 28 45 Materials and other 38 29 Total inventory $ 83 $ 89

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment, net consists of LNG terminal costs and fixed assets, as follows (in millions): June 30, December 31, 2017 2016 LNG terminal costs LNG terminal $ 7,712 $ 5,270 LNG terminal construction-in-process 5,137 6,675 Accumulated depreciation (185 ) (75 ) Total LNG terminal costs, net 12,664 11,870 Fixed assets Fixed assets 9 9 Accumulated depreciation (5 ) (4 ) Total fixed assets, net 4 5 Property, plant and equipment, net $ 12,668 $ 11,875 Depreciation expense was $66 million and $8 million in the three months ended June 30, 2017 and 2016 , respectively, and $111 million and $9 million in the six months ended June 30, 2017 and 2016 , respectively. We realized offsets to LNG terminal costs of $39 million and $128 million in the three months ended June 30, 2017 and 2016 , respectively, and $163 million and $142 million in the six months ended June 30, 2017 and 2016 , respectively, that were related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Train of the Liquefaction Project , during the testing phase for its construction.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2017
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”) and • 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 (collectively, the “Liquefaction Supply 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 to the extent not utilized for the commissioning process. The following table (in millions) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of June 30, 2017 and December 31, 2016 , 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 June 30, 2017 December 31, 2016 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 $ — $ — $ — $ — $ — $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives asset (liability) 2 — 40 42 (4 ) (2 ) 79 73 There have been no changes to our evaluation of and accounting for our derivative positions during the six months ended June 30, 2017 . See Note 7—Derivative Instruments of our Notes to Financial Statements in our annual report on Form 10-K for the year ended December 31, 2016 for additional information. We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. The fair value of our 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 satisfaction of conditions precedent, including 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. 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 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 June 30, 2017 and December 31, 2016 , some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of June 30, 2017 : Net Fair Value Asset (in millions) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $40 Income Approach Basis Spread $(0.338) - $0.080 The following table (in millions) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Balance, beginning of period $ 41 $ 30 $ 79 $ 32 Realized and mark-to-market losses: Included in cost of sales (1) (1 ) (8 ) (40 ) (10 ) Purchases and settlements: Purchases 2 — 5 — Settlements (1) (2 ) — (4 ) — Balance, end of period $ 40 $ 22 $ 40 $ 22 Change in unrealized gains relating to instruments still held at end of period $ (1 ) $ (8 ) $ (40 ) $ (9 ) (1) Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the six months ended June 30, 2016 . 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. Our derivative instruments are subject to contractual provisions which provide for the unconditional right of set-off for all derivative assets and liabilities with a given counterparty in the event of default. Interest Rate Derivatives We had 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”) . In March 2017, we settled the Interest Rate Derivatives and recognized a derivative loss of $7 million in conjunction with the termination of approximately $1.6 billion of commitments under the 2015 Credit Facilities , as discussed in Note 9—Debt . The following table (in millions) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location June 30, 2017 December 31, 2016 Interest Rate Derivatives Derivative liabilities $ — $ (4 ) Interest Rate Derivatives Non-current derivative liabilities — (2 ) The following table (in millions) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Interest Rate Derivatives loss $ — $ (5 ) $ (2 ) $ (16 ) Liquefaction Supply Derivatives The following table (in millions) shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets: Fair Value Measurements as of (1) Balance Sheet Location June 30, 2017 December 31, 2016 Liquefaction Supply Derivatives Other current assets $ 13 $ 13 Liquefaction Supply Derivatives Non-current derivative assets 32 67 Liquefaction Supply Derivatives Derivative liabilities (2 ) (7 ) Liquefaction Supply Derivatives Non-current derivative liabilities (1 ) — (1) Does not include collateral of $6 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2016 . We had secured up to approximately 2,220 TBtu and 1,994 TBtu of natural gas feedstock through natural gas supply contracts as of June 30, 2017 and December 31, 2016 , respectively. The notional natural gas position of our Liquefaction Supply Derivatives was approximately 1,424 TBtu and 1,117 TBtu as of June 30, 2017 and December 31, 2016 , respectively. The following table (in millions) shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, Statement of Operations Location (1) 2017 2016 2017 2016 Liquefaction Supply Derivatives loss (2) Cost of sales $ 1 $ 8 $ 40 $ 12 (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Does not include the realized value associated with derivative instruments that settle through physical delivery. Balance Sheet Presentation Our derivative instruments are presented on a net basis on our Balance Sheets as described above. The following table (in millions) 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 June 30, 2017 Liquefaction Supply Derivatives $ 49 $ (4 ) $ 45 Liquefaction Supply Derivatives (4 ) 1 (3 ) As of December 31, 2016 Interest Rate Derivatives $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives 82 (2 ) 80 Liquefaction Supply Derivatives (11 ) 4 (7 )

Other Non-Current Assets

Other Non-Current Assets	6 Months Ended
	Jun. 30, 2017
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS As of June 30, 2017 and December 31, 2016 , other non-current assets consisted of the following (in millions): June 30, December 31, 2017 2016 Advances made under EPC and non-EPC contracts $ 19 $ 23 Advances made to municipalities for water system enhancements 95 95 Advances and other asset conveyances to third parties to support LNG terminals 30 31 Tax-related payments and receivables 8 3 Information technology service assets 20 22 Other 1 11 Total other non-current assets, net $ 173 $ 185

Accrued Liabilities

Accrued Liabilities	6 Months Ended
	Jun. 30, 2017
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of June 30, 2017 and December 31, 2016 , accrued liabilities consisted of the following (in millions): June 30, December 31, 2017 2016 Interest costs and related debt fees $ 190 $ 204 Liquefaction Project costs 265 203 Total accrued liabilities $ 455 $ 407

Debt

Debt	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Debt	DEBT As of June 30, 2017 and December 31, 2016 , our debt consisted of the following (in millions): June 30, December 31, 2017 2016 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $6 and $7 $ 2,006 $ 2,007 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5 and $6 1,505 1,506 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 Senior Notes”), net of unamortized discount of $1 and zero 1,349 — 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 — 2015 Credit Facilities — 314 Unamortized debt issuance costs (195 ) (178 ) Total long-term debt, net 13,465 11,649 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — 224 Total debt, net $ 13,465 $ 11,873 2017 Debt Issuances and Redemptions Senior Notes In February 2017, we issued an aggregate principal amount of $800 million of the 2037 Senior Notes on a private placement basis in reliance on the exemption from registration provided for under Section 4(a)(2) of the Securities Act of 1933, as amended. In March 2017, we issued an aggregate principal amount of $1.35 billion , before discount, of the 2028 Senior Notes . Net proceeds of the offerings of the 2037 Senior Notes and the 2028 Senior Notes were $789 million and $1.33 billion , respectively, after deducting the initial purchasers’ commissions (for the 2028 Senior Notes ) and estimated fees and expenses. The net proceeds of the 2037 Senior Notes , after provisioning for incremental interest required during construction, were used to repay the then outstanding borrowings of $369 million under the 2015 Credit Facilities and, along with the net proceeds of the 2028 Senior Notes , the remainder is 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 . In connection with the issuance of the 2037 Senior Notes and the 2028 Senior Notes , we terminated the remaining available balance of $1.6 billion under the 2015 Credit Facilities , resulting in a write-off of debt issuance costs associated with the 2015 Credit Facilities of $42 million during the six months ended June 30, 2017 . The 2037 Senior Notes and the 2028 Senior Notes accrue interest at fixed rates of 5.00% and 4.200% , respectively, and interest is payable semi-annually in arrears. The terms of the 2037 Senior Notes are governed by an indenture which contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of our restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of our assets and enter into certain LNG sales contracts. The 2028 Senior Notes are governed by the same common indenture as our senior notes other than the 2037 Senior Notes , which also contains customary terms and events of default, covenants and redemption terms. At any time prior to six months before the respective dates of maturity of the 2037 Senior Notes and the 2028 Senior Notes , we may redeem all or part of such notes at a redemption price equal to the “optional redemption” price for the 2037 Senior Notes or the “make-whole” price for the 2028 Senior Notes , as set forth in the respective indentures governing the notes, plus accrued and unpaid interest, if any, to the date of redemption. We may also, at any time within six months of the respective maturity dates for the 2037 Senior Notes and the 2028 Senior Notes , redeem all or part of such notes at a redemption price equal to 100% of the principal amount of such notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption. Credit Facilities Below is a summary (in millions) of our Working Capital Facility as of June 30, 2017 : Working Capital Facility Original facility size $ 1,200 Outstanding balance — Letters of credit issued 366 Available commitment $ 834 Interest rate LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020, with various terms for underlying loans Interest Expense Total interest expense consisted of the following (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Total interest cost $ 197 $ 153 $ 383 $ 300 Capitalized interest (70 ) (126 ) (151 ) (267 ) Total interest expense, net $ 127 $ 27 $ 232 $ 33 Fair Value Disclosures The following table (in millions) shows the carrying amount and estimated fair value of our debt: June 30, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes, net of premium or discount (1) $ 12,860 $ 14,040 $ 11,513 $ 12,309 2037 Senior Notes (2) 800 860 — — Credit facilities (3) — — 538 538 (1) Includes 2021 Senior Notes , 2022 Senior Notes , 2023 Senior Notes , 2024 Senior Notes , 2025 Senior Notes , 2026 Senior Notes , 2027 Senior Notes and 2028 Senior Notes . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. (3) 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	6 Months Ended
	Jun. 30, 2017
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 six months ended June 30, 2017 and 2016 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 422 $ — $ 753 $ — Cost of sales—affiliate Cargo loading fees under TUA 6 1 10 1 Operating and maintenance expense—affiliate TUA 48 10 81 10 Natural Gas Transportation Agreement 20 8 36 8 Services Agreements 15 4 25 5 Total operating and maintenance expense—affiliate 83 22 142 23 General and administrative expense—affiliate Services Agreements 17 16 34 33 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 the Liquefaction Project . We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA . In connection with the assignment, we, Cheniere Investments and SPLNG also entered into a terminal use rights assignment and agreement (the “TURA”) pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees required by the TUA to SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal and its respective percentage of TUA fees payable is reduced from 100% to zero as each of Trains 1 through 4 reaches commercial operations, unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations. The following table shows the percentages of all TUA Fees payable to SPLNG by Cheniere Investments and us in accordance with the TURA : Period Percentage of TUA Fees Payable by Investments Percentage of TUA Fees Payable by SPL Prior to May 2016 (substantial completion of Train 1) 100% 0% May 2016 - September 2016 (substantial completion of Train 2) 75% 25% September 2016 - March 2017 (substantial completion of Train 3) 50% 50% March 2017 through substantial completion of Train 4 25% 75% After substantial completion of Train 4 0% 100% Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA . Cargo loading fees incurred under the TUA 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, which 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 We have 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 Under the Cheniere Marketing Master SPA, we have 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 We have entered into an agreement with Cheniere Marketing that authorizes Cheniere Marketing to act on our behalf to market and sell certain quantities of 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 As of June 30, 2017 and December 31, 2016 , we had $33 million and $26 million of advances to affiliates, respectively, under the services agreements described below. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate. 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 each Train of 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 each Train is operational, the services include all necessary services required to operate and maintain the Train. Prior to the substantial completion of each Train of the Liquefaction Project , 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 Train 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 the Train. Liquefaction MSA We have entered into a management services agreement (the “Liquefaction MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement . The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project . Prior to the substantial completion of each Train of the Liquefaction Project , 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 $1 million . 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 five years based on a consumer price index, as defined in the sublease agreements. Cooperation Agreement We have entered into a cooperation 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 $253 million of assets for the three and six months ended June 30, 2016 which were recorded as non-cash distributions to affiliates. We did no t convey any assets to SPLNG under this agreement during the six months ended June 30, 2017 . 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 We have 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.

Customer Concentration

Customer Concentration	6 Months Ended
	Jun. 30, 2017
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The following table shows customers with revenues of 10% or greater of total third-party revenues and customers with accounts receivable balances of 10% or greater of total accounts receivable from third parties: Percentage of Total Revenues Percentage of Accounts Receivable Three Months Ended June 30, Six Months Ended June 30, June 30, December 31, 2017 2016 2017 2016 2017 2016 Customer A 53% 96% 57% 96% 38% 47% Customer B 30% —% 32% —% 35% 50% Customer C 15% —% * —% 17% —% * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2017
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table (in millions) provides supplemental disclosure of cash flow information: Six Months Ended June 30, 2017 2016 Cash paid during the period for interest, net of amounts capitalized $ 231 $ 25 Non-cash distributions to affiliates for conveyance of assets — 253 The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $261 million and $314 million , as of June 30, 2017 and 2016 , respectively.

Recent Accounting Standards

Recent Accounting Standards	6 Months Ended
	Jun. 30, 2017
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 June 30, 2017 : 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 provides a single, comprehensive revenue recognition model which replaces and supersedes most 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. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The Financial Accounting Standards Board has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease 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 continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases on our Balance Sheets will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. 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 2015-11, 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 The adoption of this guidance did not have a material impact on our Financial Statements or related disclosures.

Nature of Operations and Basi20

Nature of Operations and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with 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 and should be read in conjunction with the Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2016 . In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows.
Income Taxes, Policy	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.

Restricted Cash (Tables)

Restricted Cash (Tables)	6 Months Ended
	Jun. 30, 2017
Restricted Cash [Abstract]
Schedule of Restricted Cash	As of June 30, 2017 and December 31, 2016 , restricted cash consisted of the following (in millions): June 30, December 31, 2017 2016 Current restricted cash Liquefaction Project $ 579 $ 358 Non-current restricted cash Liquefaction Project 698 —

Accounts and Other Receivables

Accounts and Other Receivables (Tables)	6 Months Ended
	Jun. 30, 2017
Receivables [Abstract]
Schedule of Accounts and Other Receivables	As of June 30, 2017 and December 31, 2016 , accounts and other receivables consisted of the following (in millions): June 30, December 31, 2017 2016 Trade receivable $ 123 $ 88 Other accounts receivable 15 2 Total accounts and other receivables $ 138 $ 90

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2017
Inventory Disclosure [Abstract]
Schedule of Inventory	As of June 30, 2017 and December 31, 2016 , inventory consisted of the following (in millions): June 30, December 31, 2017 2016 Natural gas $ 17 $ 15 LNG 28 45 Materials and other 38 29 Total inventory $ 83 $ 89

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment, net consists of LNG terminal costs and fixed assets, as follows (in millions): June 30, December 31, 2017 2016 LNG terminal costs LNG terminal $ 7,712 $ 5,270 LNG terminal construction-in-process 5,137 6,675 Accumulated depreciation (185 ) (75 ) Total LNG terminal costs, net 12,664 11,870 Fixed assets Fixed assets 9 9 Accumulated depreciation (5 ) (4 ) Total fixed assets, net 4 5 Property, plant and equipment, net $ 12,668 $ 11,875

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Assets and Liabilities	The following table (in millions) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of June 30, 2017 and December 31, 2016 , 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 June 30, 2017 December 31, 2016 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 $ — $ — $ — $ — $ — $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives asset (liability) 2 — 40 42 (4 ) (2 ) 79 73
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 June 30, 2017 : Net Fair Value Asset (in millions) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $40 Income Approach Basis Spread $(0.338) - $0.080
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The following table (in millions) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Balance, beginning of period $ 41 $ 30 $ 79 $ 32 Realized and mark-to-market losses: Included in cost of sales (1) (1 ) (8 ) (40 ) (10 ) Purchases and settlements: Purchases 2 — 5 — Settlements (1) (2 ) — (4 ) — Balance, end of period $ 40 $ 22 $ 40 $ 22 Change in unrealized gains relating to instruments still held at end of period $ (1 ) $ (8 ) $ (40 ) $ (9 ) (1) Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the six months ended June 30, 2016
Derivative Net Presentation on Balance Sheets	The following table (in millions) 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 June 30, 2017 Liquefaction Supply Derivatives $ 49 $ (4 ) $ 45 Liquefaction Supply Derivatives (4 ) 1 (3 ) As of December 31, 2016 Interest Rate Derivatives $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives 82 (2 ) 80 Liquefaction Supply Derivatives (11 ) 4 (7 )
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in millions) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location June 30, 2017 December 31, 2016 Interest Rate Derivatives Derivative liabilities $ — $ (4 ) Interest Rate Derivatives Non-current derivative liabilities — (2 )
Derivative Instruments, Gain (Loss)	The following table (in millions) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Interest Rate Derivatives loss $ — $ (5 ) $ (2 ) $ (16 )
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in millions) shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets: Fair Value Measurements as of (1) Balance Sheet Location June 30, 2017 December 31, 2016 Liquefaction Supply Derivatives Other current assets $ 13 $ 13 Liquefaction Supply Derivatives Non-current derivative assets 32 67 Liquefaction Supply Derivatives Derivative liabilities (2 ) (7 ) Liquefaction Supply Derivatives Non-current derivative liabilities (1 ) — (1) Does not include collateral of $6 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2016
Derivative Instruments, Gain (Loss)	The following table (in millions) shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three and six months ended June 30, 2017 and 2016 : Three Months Ended June 30, Six Months Ended June 30, Statement of Operations Location (1) 2017 2016 2017 2016 Liquefaction Supply Derivatives loss (2) Cost of sales $ 1 $ 8 $ 40 $ 12 (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) 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)	6 Months Ended
	Jun. 30, 2017
Other Assets, Noncurrent [Abstract]
Schedule of Other Non-Current Assets	As of June 30, 2017 and December 31, 2016 , other non-current assets consisted of the following (in millions): June 30, December 31, 2017 2016 Advances made under EPC and non-EPC contracts $ 19 $ 23 Advances made to municipalities for water system enhancements 95 95 Advances and other asset conveyances to third parties to support LNG terminals 30 31 Tax-related payments and receivables 8 3 Information technology service assets 20 22 Other 1 11 Total other non-current assets, net $ 173 $ 185

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2017
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of June 30, 2017 and December 31, 2016 , accrued liabilities consisted of the following (in millions): June 30, December 31, 2017 2016 Interest costs and related debt fees $ 190 $ 204 Liquefaction Project costs 265 203 Total accrued liabilities $ 455 $ 407

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of June 30, 2017 and December 31, 2016 , our debt consisted of the following (in millions): June 30, December 31, 2017 2016 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $6 and $7 $ 2,006 $ 2,007 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5 and $6 1,505 1,506 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 Senior Notes”), net of unamortized discount of $1 and zero 1,349 — 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 — 2015 Credit Facilities — 314 Unamortized debt issuance costs (195 ) (178 ) Total long-term debt, net 13,465 11,649 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — 224 Total debt, net $ 13,465 $ 11,873
Schedule of Line of Credit Facilities	Below is a summary (in millions) of our Working Capital Facility as of June 30, 2017 : Working Capital Facility Original facility size $ 1,200 Outstanding balance — Letters of credit issued 366 Available commitment $ 834 Interest rate LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020, with various terms for underlying loans
Schedule of Interest Expense	Total interest expense consisted of the following (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Total interest cost $ 197 $ 153 $ 383 $ 300 Capitalized interest (70 ) (126 ) (151 ) (267 ) Total interest expense, net $ 127 $ 27 $ 232 $ 33
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table (in millions) shows the carrying amount and estimated fair value of our debt: June 30, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes, net of premium or discount (1) $ 12,860 $ 14,040 $ 11,513 $ 12,309 2037 Senior Notes (2) 800 860 — — Credit facilities (3) — — 538 538 (1) Includes 2021 Senior Notes , 2022 Senior Notes , 2023 Senior Notes , 2024 Senior Notes , 2025 Senior Notes , 2026 Senior Notes , 2027 Senior Notes and 2028 Senior Notes . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. (3) 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)	6 Months Ended
	Jun. 30, 2017
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 six months ended June 30, 2017 and 2016 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 422 $ — $ 753 $ — Cost of sales—affiliate Cargo loading fees under TUA 6 1 10 1 Operating and maintenance expense—affiliate TUA 48 10 81 10 Natural Gas Transportation Agreement 20 8 36 8 Services Agreements 15 4 25 5 Total operating and maintenance expense—affiliate 83 22 142 23 General and administrative expense—affiliate Services Agreements 17 16 34 33
Schedule of Percentage of TUA Fees Payable	The following table shows the percentages of all TUA Fees payable to SPLNG by Cheniere Investments and us in accordance with the TURA : Period Percentage of TUA Fees Payable by Investments Percentage of TUA Fees Payable by SPL Prior to May 2016 (substantial completion of Train 1) 100% 0% May 2016 - September 2016 (substantial completion of Train 2) 75% 25% September 2016 - March 2017 (substantial completion of Train 3) 50% 50% March 2017 through substantial completion of Train 4 25% 75% After substantial completion of Train 4 0% 100%

Customer Concentration (Tables)

Customer Concentration (Tables)	6 Months Ended
	Jun. 30, 2017
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	The following table shows customers with revenues of 10% or greater of total third-party revenues and customers with accounts receivable balances of 10% or greater of total accounts receivable from third parties: Percentage of Total Revenues Percentage of Accounts Receivable Three Months Ended June 30, Six Months Ended June 30, June 30, December 31, 2017 2016 2017 2016 2017 2016 Customer A 53% 96% 57% 96% 38% 47% Customer B 30% —% 32% —% 35% 50% Customer C 15% —% * —% 17% —% * Less than 10%

Supplemental Cash Flow Inform31

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2017
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table (in millions) provides supplemental disclosure of cash flow information: Six Months Ended June 30, 2017 2016 Cash paid during the period for interest, net of amounts capitalized $ 231 $ 25 Non-cash distributions to affiliates for conveyance of assets — 253

Recent Accounting Standards (Ta

Recent Accounting Standards (Tables)	6 Months Ended
	Jun. 30, 2017
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 June 30, 2017 : 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 provides a single, comprehensive revenue recognition model which replaces and supersedes most 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. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The Financial Accounting Standards Board has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease 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 continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases on our Balance Sheets will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. 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 2015-11, 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 The adoption of this guidance did not have a material impact on our Financial Statements or related disclosures.

Nature of Operations and Basi33

Nature of Operations and Basis of Presentation (Details)	6 Months Ended
	Jun. 30, 2017USD ($)trains
Nature of Operations and Basis of Presentation [Line Items]
Income Tax Expense (Benefit) | $	$ 0
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains | trains	6

Restricted Cash (Details)

Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	$ 579	$ 358
Non-current restricted cash	698	0
Liquefaction Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	579	358
Non-current restricted cash	$ 698	$ 0

Accounts and Other Receivable35

Accounts and Other Receivables (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Receivables [Abstract]
Trade receivable	$ 123	$ 88
Other accounts receivable	15	2
Total accounts and other receivables	$ 138	$ 90

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Inventory [Line Items]
Inventory	$ 83	$ 89
Natural gas [Member]
Inventory [Line Items]
Inventory	17	15
LNG [Member]
Inventory [Line Items]
Inventory	28	45
Materials and other [Member]
Inventory [Line Items]
Inventory	$ 38	$ 29

Property, Plant and Equipment37

Property, Plant and Equipment (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 12,668		$ 12,668		$ 11,875
Depreciation expense	66	$ 8	111	$ 9
Offsets to LNG terminal costs	39	$ 128	163	$ 142
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(185)		(185)		(75)
Property, plant and equipment, net	12,664		12,664		11,870
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,712		7,712		5,270
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	5,137		5,137		6,675
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	9		9		9
Accumulated depreciation	(5)		(5)		(4)
Property, plant and equipment, net	$ 4		$ 4		$ 5

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) $ in Millions	1 Months Ended	6 Months Ended
	Mar. 31, 2017USD ($)	Jun. 30, 2017USD ($)tbtu	Dec. 31, 2016tbtu
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Energy Units Secured Through Natural Gas Supply Contracts | tbtu		2,220	1,994
2015 Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease | $	$ 1,600	$ 1,600
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net | $	$ 7
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount | tbtu		1,424	1,117

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ (6)
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	0	(6)
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	42	73
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	2	(4)
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	(2)
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	$ 40	$ 79

Derivative Instruments - Fair40

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member]	6 Months Ended
	Jun. 30, 2017USD ($)
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$ 40,000,000
Valuation Technique	Income Approach
Significant Unobservable Input	Basis Spread
Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ (0.338)
Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ 0.080

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period	$ 41	$ 30	$ 79	$ 32
Realized and mark-to-market losses:
Included in cost of sales	(1)	(8)	(40)	(10)	[1]
Purchases and settlements:
Purchases	2	0	5	0
Settlements	(2)	0	(4)	0	[1]
Balance, end of period	40	22	40	22
Change in unrealized gains relating to instruments still held at end of period	$ (1)	$ (8)	$ (40)	(9)
Decrease in Fair Value Realized and Capitalized During Period				$ 1
[1]	Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the six months ended June 30, 2016.

Derivative Instruments - Fair42

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Non-current derivative assets	$ 32	$ 67
Derivative liabilities	(2)	(11)
Non-current derivative liabilities	(1)	(2)
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0	(4)
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	0	(2)
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	13	13	[1]
Derivative, Collateral, Right to Reclaim Cash		6
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	32	67	[1]
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(2)	(7)	[1]
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	$ (1)	$ 0	[1]
[1]	Does not include collateral of $6 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2016.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended		6 Months Ended
		Mar. 31, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Interest Rate Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative loss, net		$ (7)
Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative loss, net			$ 0	$ (5)	$ (2)	$ (16)
Liquefaction Supply Derivatives [Member] | Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative loss, net	[1],[2]		$ (1)	$ (8)	$ (40)	$ (12)
[1]	Does not include the realized value associated with derivative instruments that settle through physical delivery.
[2]	Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

Derivative Instruments - Deri44

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Interest Rate Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized		$ (6)
Derivative Liability, Gross Amounts Offset in the Balance Sheets		0
Net Amounts Presented in our Balance Sheets		(6)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 49	82
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(4)	(2)
Net Amounts Presented in our Balance Sheets	45	80
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(4)	(11)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	1	4
Net Amounts Presented in our Balance Sheets	$ (3)	$ (7)

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Other Assets, Noncurrent [Abstract]
Advances made under EPC and non-EPC contracts	$ 19	$ 23
Advances made to municipalities for water system enhancements	95	95
Advances and other asset conveyances to third parties to support LNG terminals	30	31
Tax-related payments and receivables	8	3
Information technology service assets	20	22
Other	1	11
Other non-current assets, net	$ 173	$ 185

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 190	$ 204
Liquefaction Project costs	265	203
Total accrued liabilities	$ 455	$ 407

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Long-term Debt, Net	$ 13,465,000,000	$ 11,649,000,000
Unamortized Debt Issuance Costs, Noncurrent	(195,000,000)	(178,000,000)
Current Debt, Working Capital Facility	0	224,000,000
Total Debt, Net	13,465,000,000	11,873,000,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 2,006,000,000	2,007,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Debt Instrument, Unamortized Premium	$ 6,000,000	7,000,000
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	$ 1,505,000,000	1,506,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Debt Instrument, Unamortized Premium	$ 5,000,000	6,000,000
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	1,500,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,500,000,000	1,500,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,349,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Debt Instrument, Unamortized Discount	$ 1,000,000	0
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 800,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.00%
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 0	314,000,000
Working Capital Facility [Member]
Debt Instrument [Line Items]
Current Debt, Working Capital Facility	0	$ 224,000,000
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,200,000,000

Debt - Debt Issuances and Redem

Debt - Debt Issuances and Redemptions (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Debt Instrument [Line Items]
Loss on early extinguishment of debt			$ 0	$ 26	$ 42	$ 26
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate principal amount		$ 800
Proceeds from issuances of long-term debt		$ 789
Debt Instrument, Interest Rate, Stated Percentage			5.00%		5.00%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Optional Redemption Price					6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount					6 months
Debt Instrument, Redemption Price, Percentage					100.00%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate principal amount	$ 1,350
Proceeds from issuances of long-term debt	1,330
Debt Instrument, Interest Rate, Stated Percentage			4.20%		4.20%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Make-Whole Price					6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount					6 months
Debt Instrument, Redemption Price, Percentage					100.00%
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt	369
Commitments prepaid or terminated	$ 1,600				$ 1,600
Loss on early extinguishment of debt					$ 42

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Outstanding balance	$ 0	$ 224
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	1,200
Outstanding balance	0	$ 224
Letters of credit issued	366
Available commitment	$ 834
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 Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Debt Disclosure [Abstract]
Total interest cost	$ 197	$ 153	$ 383	$ 300
Capitalized interest	(70)	(126)	(151)	(267)
Total interest expense, net	$ 127	$ 27	$ 232	$ 33

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Jun. 30, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 13,465	$ 11,873
Senior Notes, net of premium or discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	12,860	11,513
Senior Notes, net of premium or discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	14,040	12,309
2037 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	800	0
2037 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	860	0
Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[3]	0	538
Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Credit Facilities, Estimated Fair Value	[3]	$ 0	$ 538
[1]	Includes 2021 Senior Notes, 2022 Senior Notes, 2023 Senior Notes, 2024 Senior Notes, 2025 Senior Notes, 2026 Senior Notes, 2027 Senior Notes and 2028 Senior Notes. The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.
[2]	The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.
[3]	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 Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 422	$ 0	$ 753	$ 0
Cost of sales—affiliate	6	1	10	1
Operating and maintenance expense—affiliate	83	22	142	23
General and administrative expense—affiliate	17	16	34	33
Cheniere Marketing SPA and Cheniere Marketing Master SPA [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	422	0	753	0
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	6	1	10	1
Operating and maintenance expense—affiliate	48	10	81	10
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	20	8	36	8
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	15	4	25	5
General and administrative expense—affiliate	$ 17	$ 16	$ 34	$ 33

Related Party Transactions - 53

Related Party Transactions - Schedule of Percentage of TUA Fees Payable (Details) - Terminal Use Rights Assignment and Agreement [Member] - SPLNG [Member]	6 Months Ended
	Jun. 30, 2017
Prior to Substantial Completion of SPL Train 1 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	0.00%
Between Substantial Completion of SPL Trains 1 and 2 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	25.00%
Between Substantial Completion of SPL Trains 2 and 3 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	50.00%
Between Substantial Completion of SPL Trains 3 and 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	75.00%
After Substantial Completion of SPL Train 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	100.00%
Cheniere Investments [Member] | Prior to Substantial Completion of SPL Train 1 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	100.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 1 and 2 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	75.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 2 and 3 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	50.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 3 and 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	25.00%
Cheniere Investments [Member] | After Substantial Completion of SPL Train 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	0.00%

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	3 Months Ended	6 Months Ended
	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)bcf / dtrains$ / MMBTU	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)
Related Party Transaction [Line Items]
Advances to affiliate		$ 33,000,000		$ 26,000,000
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
Portion of Storage Capacity Reserved		41.00%
Terminal Use Rights Assignment and 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 Rights Assignment and 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]
LNG Volume, Purchase Price Percentage of Henry Hub		115.00%
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
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate		$ 33,000,000		$ 26,000,000
Operation and Maintenance Agreement [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month		0.60%
Related Party Transaction, Committed Monthly Fee		$ 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
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment		$ 1,000,000
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	$ 253,000,000	$ 0	$ 253,000,000
Tax Sharing Agreement [Member] | Cheniere [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net		$ 0

Customer Concentration (Details

Customer Concentration (Details)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Customer A [Member] | Total Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	53.00%	96.00%	57.00%	96.00%
Customer A [Member] | Accounts Receivable [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			38.00%		47.00%
Customer B [Member] | Total Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	30.00%	0.00%	32.00%	0.00%
Customer B [Member] | Accounts Receivable [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			35.00%		50.00%
Customer C [Member] | Total Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15.00%	0.00%		0.00%
Customer C [Member] | Accounts Receivable [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			17.00%		0.00%

Supplemental Cash Flow Inform56

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 231	$ 25
Non-cash distributions to affiliates for conveyance of assets	0	253
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$ 261	$ 314