Sabine Pass Liquefaction 10-Q 8 Aug 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2019shares
Cover page.
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	333-192373
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	27-3235920
Entity Address, Address Line One	700 Milam Street
Entity Address, Address Line Two	Suite 1900
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	375-5000
Title of 12(b) Security	None
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001499200
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
No Trading Symbol Flag	true
Entity Common Stock, Shares Outstanding	0

Balance Sheets

Balance Sheets - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Current assets
Cash and cash equivalents	$ 0	$ 0
Restricted cash	596	756
Accounts and other receivables	240	346
Accounts receivable—affiliate	166	113
Advances to affiliate	206	210
Inventory	91	87
Derivative assets	17	6
Other current assets	54	18
Other current assets—affiliate	21	21
Total current assets	1,391	1,557
Property, plant and equipment, net	13,722	13,209
Debt issuance costs, net	9	12
Non-current derivative assets	37	31
Other non-current assets, net	153	158
Total assets	15,312	14,967
Current liabilities
Accounts payable	67	11
Accrued liabilities	1,011	768
Due to affiliates	44	48
Deferred revenue	101	91
Derivative liabilities	8	66
Total current liabilities	1,231	984
Long-term debt, net	13,512	13,500
Non-current derivative liabilities	12	14
Other non-current liabilities	7	3
Other non-current liabilities—affiliate	16	0
Member’s equity	534	466
Total liabilities and member’s equity	$ 15,312	$ 14,967

Statements of Income

Statements of Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenues
Revenues	$ 1,626	$ 1,333	$ 3,298	$ 2,851
Revenues from contracts with customers	1,626	1,333	3,297	2,851
Operating costs and expenses
Cost of sales (excluding depreciation and amortization expense shown separately below)	880	695	1,759	1,533
Cost of sales—affiliate	9	7	18	15
Operating and maintenance expense	138	84	248	162
Operating and maintenance expense—affiliate	115	107	222	210
Development expense	0	1	0	1
General and administrative expense	2	1	3	3
General and administrative expense—affiliate	21	12	36	24
Depreciation and amortization expense	118	87	214	173
Impairment expense and loss on disposal of assets	3	0	5	0
Total operating costs and expenses	1,286	994	2,505	2,121
Income from operations	340	339	793	730
Other income (expense)
Interest expense, net of capitalized interest	(191)	(148)	(341)	(299)
Other income	1	2	6	4
Total other expense	(190)	(146)	(335)	(295)
Net income	150	193	458	435
LNG [Member]
Revenues
Revenues	1,171	1,155	2,538	2,170
Revenues from contracts with customers	1,171	1,155	2,537	2,170
LNG—affiliate [Member]
Revenues
Revenues from contracts with customers	$ 455	$ 178	$ 760	$ 681

Statements of Member's Equity

Statements of Member's Equity - USD ($) $ in Millions	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2017	$ (38)	$ (38)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	242	242
Member's equity, end of period at Mar. 31, 2018	204	204
Members' equity, beginning of period at Dec. 31, 2017	(38)	(38)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	435
Member's equity, end of period at Jun. 30, 2018	422	422
Members' equity, beginning of period at Mar. 31, 2018	204	204
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions	25	25
Net income	193	193
Member's equity, end of period at Jun. 30, 2018	422	422
Members' equity, beginning of period at Dec. 31, 2018	466	466
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions	164	164
Distributions	(231)	(231)
Net income	308	308
Member's equity, end of period at Mar. 31, 2019	707	707
Members' equity, beginning of period at Dec. 31, 2018	466	466
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	458
Member's equity, end of period at Jun. 30, 2019	534	534
Members' equity, beginning of period at Mar. 31, 2019	707	707
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions	642	642
Distributions	(965)	(965)
Net income	150	150
Member's equity, end of period at Jun. 30, 2019	$ 534	$ 534

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash flows from operating activities
Net income	$ 458	$ 435
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	214	173
Amortization of debt issuance costs, deferred commitment fees, premium and discount	13	11
Total losses (gains) on derivatives, net	(84)	52
Net cash provided by (used for) settlement of derivative instruments	7	(6)
Impairment expense and loss on disposal of assets	5	0
Changes in operating assets and liabilities:
Accounts and other receivables	71	(47)
Accounts receivable—affiliate	(53)	142
Advances to affiliate	(29)	(70)
Inventory	(3)	9
Accounts payable and accrued liabilities	(135)	(62)
Due to affiliates	3	(10)
Deferred revenue	9	(11)
Other, net	(26)	(12)
Net cash provided by operating activities	450	604
Cash flows from investing activities
Property, plant and equipment, net	(567)	(327)
Other	(1)	0
Net cash used in investing activities	(568)	(327)
Cash flows from financing activities
Capital contributions	806	25
Distributions	(848)	0
Net cash provided by (used in) financing activities	(42)	25
Net increase (decrease) in cash, cash equivalents and restricted cash	(160)	302
Cash, cash equivalents and restricted cash—beginning of period	756	544
Cash, cash equivalents and restricted cash—end of period	$ 596	$ 846

Statements of Cash Flows - Bala

Statements of Cash Flows - Balances per Balance Sheets - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Balances per Balance Sheets:
Cash and cash equivalents	$ 0	$ 0
Restricted cash	596	756
Total cash, cash equivalents and restricted cash	$ 596	$ 756	$ 846	$ 544

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We are in various stages of constructing and operating six natural gas liquefaction facilities (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 constructed and operated at the Sabine Pass LNG terminal, which is located on the Sabine-Neches Waterway less than four miles from the Gulf Coast . Trains 1 through 5 are operational and Train 6 is under construction. 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, 2018 . Results of operations for the three and six months ended June 30, 2019 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2019 . 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 reported on our Statements of Income, 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. Recent Accounting Standards We adopted ASU 2016-02, Leases (Topic 842) , and subsequent amendments thereto on January 1, 2019 using the optional transition approach to apply the standard at the beginning of the first quarter of 2019 with no retrospective adjustments to prior periods. 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. The adoption of the standard did not materially impact our Financial Statements. Upon adoption of the standard we recorded right-of-use assets of $20 million in other non-current assets, net, and lease liabilities of $4 million in other non-current liabilities and $16 million in other non-current liabilities—affiliate.

Restricted Cash

Restricted Cash	6 Months Ended
	Jun. 30, 2019
Restricted Cash [Abstract]
Restricted Cash	RESTRICTED CASH Restricted cash consists of funds that are contractually and legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. As of June 30, 2019 and December 31, 2018 , restricted cash consisted of the following (in millions): June 30, December 31, 2019 2018 Current restricted cash Liquefaction Project $ 596 $ 756 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

Accounts and Other Receivables

Accounts and Other Receivables	6 Months Ended
	Jun. 30, 2019
Receivables [Abstract]
Accounts and Other Receivables	ACCOUNTS AND OTHER RECEIVABLES As of June 30, 2019 and December 31, 2018 , accounts and other receivables consisted of the following (in millions): June 30, December 31, 2019 2018 Trade receivable $ 234 $ 330 Other accounts receivable 6 16 Total accounts and other receivables $ 240 $ 346

Inventory

Inventory	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of June 30, 2019 and December 31, 2018 , inventory consisted of the following (in millions): June 30, December 31, 2019 2018 Natural gas $ 15 $ 28 LNG 9 6 Materials and other 67 53 Total inventory $ 91 $ 87

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT As of June 30, 2019 and December 31, 2018 , property, plant and equipment, net consisted of the following (in millions): June 30, December 31, 2019 2018 LNG terminal costs LNG terminal $ 13,644 $ 10,004 LNG terminal construction-in-process 947 3,866 Accumulated depreciation (875 ) (667 ) Total LNG terminal costs, net 13,716 13,203 Fixed assets Fixed assets 16 14 Accumulated depreciation (10 ) (8 ) Total fixed assets, net 6 6 Property, plant and equipment, net $ 13,722 $ 13,209 Depreciation expense was $118 million and $85 million during the three months ended June 30, 2019 and 2018 , respectively, and $212 million and $169 million during the six months ended June 30, 2019 and 2018 , respectively. We realized offsets to LNG terminal costs of $48 million during the six months ended June 30, 2019 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 Trains of the Liquefaction Project , during the testing phase for its construction. We did no t realize any offsets to LNG terminal costs during the three months ended June 30, 2019 and the three and six months ended June 30, 2018 .

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into 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”) . We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Income to the extent not utilized for the commissioning process. The following table 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, 2019 and December 31, 2018 , which are classified as derivative assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets (in millions): Fair Value Measurements as of June 30, 2019 December 31, 2018 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 Liquefaction Supply Derivatives asset (liability) $ 1 $ (1 ) $ 34 $ 34 $ 5 $ (23 ) $ (25 ) $ (43 ) We value our Liquefaction Supply Derivatives using a market-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available and other relevant data. The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of June 30, 2019 and December 31, 2018 , some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow. We include a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which may be impacted by inputs that are unobservable in the marketplace. 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. The Level 3 fair value measurements of our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas market basis spreads due to the contractual notional amount represented by our Level 3 positions, which is a substantial portion of our overall Physical Liquefaction Supply Derivatives portfolio. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of June 30, 2019 : Net Fair Value Asset (in millions) Valuation Approach Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $34 Market approach incorporating present value techniques Henry Hub Basis Spread $(0.350) - $0.056 The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Balance, beginning of period $ 29 $ 10 $ (25 ) $ 43 Realized and mark-to-market gains (losses): Included in cost of sales 3 (1 ) 16 (13 ) Purchases and settlements: Purchases 1 6 — 6 Settlements 1 (4 ) 43 (25 ) Balance, end of period $ 34 $ 11 $ 34 $ 11 Change in unrealized gains (losses) relating to instruments still held at end of period $ 3 $ (1 ) $ 16 $ (13 ) 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 the unconditional right of set-off in the event of default. 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. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of netting and any applicable credit enhancements, such as collateral postings, set-off rights and guarantees. Liquefaction Supply Derivatives We have entered into primarily 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 range up to five years , some of which commence upon the satisfaction of certain conditions precedent. We had secured up to approximately 3,437 TBtu and 3,464 TBtu of natural gas feedstock through natural gas supply contracts as of June 30, 2019 and December 31, 2018 , respectively. The notional natural gas position of our Liquefaction Supply Derivatives was approximately 3,122 TBtu and 2,978 TBtu as of June 30, 2019 and December 31, 2018 , respectively. The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheet Location June 30, 2019 December 31, 2018 Derivative assets $ 17 $ 6 Non-current derivative assets 37 31 Total derivative assets 54 37 Derivative liabilities (8 ) (66 ) Non-current derivative liabilities (12 ) (14 ) Total derivative liabilities (20 ) (80 ) Derivative asset (liability), net $ 34 $ (43 ) (1) Does not include collateral calls of $2 million and $1 million for such contracts, which are included in other current assets in our Balance Sheets as of June 30, 2019 and December 31, 2018 , respectively. The following table shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives on our Statements of Income during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, Statement of Income Location (1) 2019 2018 2019 2018 Liquefaction Supply Derivatives gain LNG revenues $ — $ — $ 1 $ — Liquefaction Supply Derivatives gain (loss) Cost of sales 7 (2 ) 83 (52 ) (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. 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. Balance Sheet Presentation Our derivative instruments are presented on a net basis on our Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions): 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, 2019 Liquefaction Supply Derivatives $ 56 $ (2 ) $ 54 Liquefaction Supply Derivatives (21 ) 1 (20 ) As of December 31, 2018 Liquefaction Supply Derivatives $ 63 $ (26 ) $ 37 Liquefaction Supply Derivatives (92 ) 12 (80 )

Other Non-Current Assets

Other Non-Current Assets	6 Months Ended
	Jun. 30, 2019
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS As of June 30, 2019 and December 31, 2018 , other non-current assets, net consisted of the following (in millions): June 30, December 31, 2019 2018 Advances made to municipalities for water system enhancements $ 89 $ 90 Advances and other asset conveyances to third parties to support LNG terminals 36 36 Operating lease assets 21 — Information technology service assets 7 16 Advances made under EPC and non-EPC contracts — 14 Other — 2 Total other non-current assets, net $ 153 $ 158

Accrued Liabilities

Accrued Liabilities	6 Months Ended
	Jun. 30, 2019
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of June 30, 2019 and December 31, 2018 , accrued liabilities consisted of the following (in millions): June 30, December 31, 2019 2018 Interest costs and related debt fees $ 230 $ 186 Accrued natural gas purchases 310 518 Liquefaction Project costs 469 64 Other accrued liabilities 2 — Total accrued liabilities $ 1,011 $ 768

Debt

Debt	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Debt	DEBT As of June 30, 2019 and December 31, 2018 , our debt consisted of the following (in millions): June 30, December 31, 2019 2018 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”) $ 2,000 $ 2,000 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”) 1,500 1,500 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”) 1,350 1,350 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 800 Unamortized discount, premium and debt issuance costs, net (138 ) (150 ) Total long-term debt, net 13,512 13,500 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — — Total debt, net $ 13,512 $ 13,500 Working Capital Facility Below is a summary of our Working Capital Facility as of June 30, 2019 (in millions): Working Capital Facility (1) Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 415 Available commitment $ 785 Interest rate on outstanding balance LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020 (1) The Working Capital Facility was amended in May 2019 in connection with commercialization and financing of Train 6 of the Liquefaction Project. All terms of the Working Capital Facility substantially remained unchanged. Restrictive Debt Covenants As of June 30, 2019 , we were in compliance with all covenants related to our debt agreements. Interest Expense Total interest expense consisted of the following (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Total interest cost $ 198 $ 198 $ 395 $ 396 Capitalized interest (7 ) (50 ) (54 ) (97 ) Total interest expense, net $ 191 $ 148 $ 341 $ 299 Fair Value Disclosures The following table shows the carrying amount, which is net of unamortized premium, discount and debt issuance costs, and estimated fair value of our debt (in millions): June 30, 2019 December 31, 2018 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes (1) $ 12,721 $ 14,041 $ 12,709 $ 13,235 2037 Senior Notes (2) 791 912 791 817 (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)

Revenues from Contracts with Cu

Revenues from Contracts with Customers	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenues from Contracts with Customers	REVENUES FROM CONTRACTS WITH CUSTOMERS The following table represents a disaggregation of revenue earned from contracts with customers during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 LNG revenues $ 1,171 $ 1,155 $ 2,537 $ 2,170 LNG revenues—affiliate 455 178 760 681 Total revenues from customers 1,626 1,333 3,297 2,851 Net derivative gains (1) — — 1 — Total revenues $ 1,626 $ 1,333 $ 3,298 $ 2,851 (1) See Note 6—Derivative Instruments for additional information about our derivatives. Deferred Revenue Reconciliation The following table reflects the changes in our contract liabilities, which we classify as deferred revenues on our Balance Sheets (in millions): Six Months Ended June 30, 2019 Deferred revenues, beginning of period $ 91 Cash received but not yet recognized 101 Revenue recognized from prior period deferral (91 ) Deferred revenues, end of period $ 101 Transaction Price Allocated to Future Performance Obligations Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Weighted Average Recognition Timing (years) (1) LNG revenues (2) $ 56.3 10 $ 53.6 10 (1) The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price. (2) Includes future consideration from agreement anticipated to be assigned to SPL from Cheniere Marketing. We have elected the following exemptions which omit certain potential future sources of revenue from the table above: (1) We omit from the table above all performance obligations that are part of a contract that has an original expected duration of one year or less. (2) We omit from the table above all variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation when that performance obligation qualifies as a series. The table above excludes substantially all variable consideration under our SPAs. The amount of revenue from variable fees that is not included in the transaction price will vary based on the future prices of Henry Hub throughout the contract terms, to the extent customers elect to take delivery of their LNG, and adjustments to the consumer price index. Approximately 53% and 55% of our LNG revenues during the three months ended June 30, 2019 and 2018 , respectively, and approximately 55% of our LNG revenues during each of the six months ended June 30, 2019 and 2018 , were related to variable consideration received from customers. All of our LNG revenues—affiliate were related to variable consideration received from customers during each of the three and six months ended June 30, 2019 and 2018 . We have entered into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching a final investment decision on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2019
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 Income for the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 LNG revenues—affiliate Cheniere Marketing Agreements $ 455 $ 178 $ 760 $ 681 Cost of sales—affiliate Cargo loading fees under TUA 9 7 18 15 Operating and maintenance expense—affiliate TUA 67 64 131 128 Natural Gas Transportation Agreement 21 21 40 41 Services Agreements 27 22 51 41 Total operating and maintenance expense—affiliate 115 107 222 210 General and administrative expense—affiliate Services Agreements 21 12 36 24 As of June 30, 2019 and December 31, 2018 , we had $166 million and $113 million of accounts receivable—affiliate, respectively, under the agreements described below. Terminal Use Agreement We have 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 May 2036. Cheniere Partners has guaranteed our obligations under our TUA . 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 share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. Cheniere Marketing Agreements Cheniere Marketing SPA Cheniere Marketing has an SPA (“ Base 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 . In May 2019, we and Cheniere Marketing entered into an amendment to the Base SPA to remove certain conditions related to the sale of LNG from Trains 5 and 6 of the Liquefaction Project and provide that cargoes rejected by Cheniere Marketing under the Base SPA can be sold by us to Cheniere Marketing at a contract price equal to a portion of the estimated net profits from the sale of such cargo. Cheniere Marketing Master SPA We have an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. We executed a confirmation with Cheniere Marketing that obligated Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the period while Bechtel Oil, Gas and Chemicals, Inc. had control of, and was commissioning, Train 5 of the Liquefaction Project. Cheniere Marketing Letter Agreement In May 2019, we and Cheniere Marketing entered into a letter agreement for the sale of up to 20 cargoes totaling approximately 70 million MMBtu scheduled for delivery between May 3 and December 31, 2019 at a price of 115% of Henry Hub plus $2.00 per MMBtu. Natural Gas Transportation Agreements To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, we have a transportation precedent agreement and a negotiated rate agreement to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of Cheniere Partners, and third-party pipeline companies. These agreements have a primary term of 20 years from commercial operation of Train 2 and thereafter continue in effect from year to year until terminated by either party upon written notice of one year or the term of the agreements, whichever is less. In addition, we have the right to elect to extend the term of the agreements for up to two consecutive terms of 10 years . Maximum rates, charges and fees shall be applicable for the entitlements and quantities delivered pursuant to the agreements unless CTPL has advised us that it has agreed otherwise. Services Agreements As of June 30, 2019 and December 31, 2018 , we had $206 million and $210 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 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 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. 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 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 Investments 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 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 periods of 10 years 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 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. We conveyed $348 million in assets to SPLNG under this agreement during the three and six months ended June 30, 2019 . We did not convey any assets to SPLNG under this agreement during the three and six months ended June 30, 2018 . Contracts for Sale and Purchase of Natural Gas and LNG We have agreements with SPLNG that allow us to sell and purchase natural gas and LNG with SPLNG. Natural gas and LNG purchased under these agreements 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 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, 2019
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The following table shows customers with revenues of 10% or greater of total revenues from external customers and customers with accounts receivable balances of 10% or greater of total accounts receivable from external customers: Percentage of Total Revenues from External Customers Percentage of Accounts Receivable from External Customers Three Months Ended June 30, Six Months Ended June 30, June 30, December 31, 2019 2018 2019 2018 2019 2018 Customer A 32% 28% 32% 31% 19% 35% Customer B 21% 23% 21% 25% 26% 23% Customer C 21% 24% 20% 25% 26% 30% Customer D 24% 21% 24% 16% 26% * * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table provides supplemental disclosure of cash flow information (in millions): Six Months Ended June 30, 2019 2018 Cash paid during the period for interest, net of amounts capitalized $ 282 $ 285 Non-cash distributions to affiliates for conveyance of assets 348 — The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $683 million and $249 million , as of June 30, 2019 and 2018 , respectively.

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	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, 2018
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 reported on our Statements of Income, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no
Recent Accounting Standards	Recent Accounting Standards We adopted ASU 2016-02, Leases (Topic 842) , and subsequent amendments thereto on January 1, 2019 using the optional transition approach to apply the standard at the beginning of the first quarter of 2019 with no retrospective adjustments to prior periods. 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. The adoption of the standard did not materially impact our Financial Statements. Upon adoption of the standard we recorded right-of-use assets of $20 million in other non-current assets, net, and lease liabilities of $4 million in other non-current liabilities and $16 million in other non-current liabilities—affiliate.

Restricted Cash (Tables)

Restricted Cash (Tables)	6 Months Ended
	Jun. 30, 2019
Restricted Cash [Abstract]
Schedule of Restricted Cash	As of June 30, 2019 and December 31, 2018 , restricted cash consisted of the following (in millions): June 30, December 31, 2019 2018 Current restricted cash Liquefaction Project $ 596 $ 756

Accounts and Other Receivables

Accounts and Other Receivables (Tables)	6 Months Ended
	Jun. 30, 2019
Receivables [Abstract]
Schedule of Accounts and Other Receivables	As of June 30, 2019 and December 31, 2018 , accounts and other receivables consisted of the following (in millions): June 30, December 31, 2019 2018 Trade receivable $ 234 $ 330 Other accounts receivable 6 16 Total accounts and other receivables $ 240 $ 346

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Schedule of Inventory	As of June 30, 2019 and December 31, 2018 , inventory consisted of the following (in millions): June 30, December 31, 2019 2018 Natural gas $ 15 $ 28 LNG 9 6 Materials and other 67 53 Total inventory $ 91 $ 87

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	As of June 30, 2019 and December 31, 2018 , property, plant and equipment, net consisted of the following (in millions): June 30, December 31, 2019 2018 LNG terminal costs LNG terminal $ 13,644 $ 10,004 LNG terminal construction-in-process 947 3,866 Accumulated depreciation (875 ) (667 ) Total LNG terminal costs, net 13,716 13,203 Fixed assets Fixed assets 16 14 Accumulated depreciation (10 ) (8 ) Total fixed assets, net 6 6 Property, plant and equipment, net $ 13,722 $ 13,209

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Value of Derivative Assets and Liabilities	The following table 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, 2019 and December 31, 2018 , which are classified as derivative assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets (in millions): Fair Value Measurements as of June 30, 2019 December 31, 2018 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 Liquefaction Supply Derivatives asset (liability) $ 1 $ (1 ) $ 34 $ 34 $ 5 $ (23 ) $ (25 ) $ (43 )
Fair Value Measurement Inputs and Valuation Techniques	The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of June 30, 2019 : Net Fair Value Asset (in millions) Valuation Approach Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $34 Market approach incorporating present value techniques Henry Hub Basis Spread $(0.350) - $0.056
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Balance, beginning of period $ 29 $ 10 $ (25 ) $ 43 Realized and mark-to-market gains (losses): Included in cost of sales 3 (1 ) 16 (13 ) Purchases and settlements: Purchases 1 6 — 6 Settlements 1 (4 ) 43 (25 ) Balance, end of period $ 34 $ 11 $ 34 $ 11 Change in unrealized gains (losses) relating to instruments still held at end of period $ 3 $ (1 ) $ 16 $ (13 )
Fair Value of Derivative Instruments by Balance Sheet Location	The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheet Location June 30, 2019 December 31, 2018 Derivative assets $ 17 $ 6 Non-current derivative assets 37 31 Total derivative assets 54 37 Derivative liabilities (8 ) (66 ) Non-current derivative liabilities (12 ) (14 ) Total derivative liabilities (20 ) (80 ) Derivative asset (liability), net $ 34 $ (43 ) (1) Does not include collateral calls of $2 million and $1 million for such contracts, which are included in other current assets in our Balance Sheets as of June 30, 2019 and December 31, 2018
Derivative Instruments, Gain (Loss)	The following table shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives on our Statements of Income during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, Statement of Income Location (1) 2019 2018 2019 2018 Liquefaction Supply Derivatives gain LNG revenues $ — $ — $ 1 $ — Liquefaction Supply Derivatives gain (loss) Cost of sales 7 (2 ) 83 (52 ) (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. 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 Net Presentation on Balance Sheets	The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions): 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, 2019 Liquefaction Supply Derivatives $ 56 $ (2 ) $ 54 Liquefaction Supply Derivatives (21 ) 1 (20 ) As of December 31, 2018 Liquefaction Supply Derivatives $ 63 $ (26 ) $ 37 Liquefaction Supply Derivatives (92 ) 12 (80 )

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	6 Months Ended
	Jun. 30, 2019
Other Assets, Noncurrent [Abstract]
Schedule of Other Non-Current Assets	As of June 30, 2019 and December 31, 2018 , other non-current assets, net consisted of the following (in millions): June 30, December 31, 2019 2018 Advances made to municipalities for water system enhancements $ 89 $ 90 Advances and other asset conveyances to third parties to support LNG terminals 36 36 Operating lease assets 21 — Information technology service assets 7 16 Advances made under EPC and non-EPC contracts — 14 Other — 2 Total other non-current assets, net $ 153 $ 158

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of June 30, 2019 and December 31, 2018 , accrued liabilities consisted of the following (in millions): June 30, December 31, 2019 2018 Interest costs and related debt fees $ 230 $ 186 Accrued natural gas purchases 310 518 Liquefaction Project costs 469 64 Other accrued liabilities 2 — Total accrued liabilities $ 1,011 $ 768

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of June 30, 2019 and December 31, 2018 , our debt consisted of the following (in millions): June 30, December 31, 2019 2018 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”) $ 2,000 $ 2,000 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”) 1,500 1,500 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”) 1,350 1,350 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 800 Unamortized discount, premium and debt issuance costs, net (138 ) (150 ) Total long-term debt, net 13,512 13,500 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — — Total debt, net $ 13,512 $ 13,500
Schedule of Line of Credit Facilities	Below is a summary of our Working Capital Facility as of June 30, 2019 (in millions): Working Capital Facility (1) Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 415 Available commitment $ 785 Interest rate on outstanding balance LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020 (1) The Working Capital Facility was amended in May 2019 in connection with commercialization and financing of Train 6 of the Liquefaction Project. All terms of the Working Capital Facility substantially remained unchanged.
Schedule of Interest Expense	Total interest expense consisted of the following (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Total interest cost $ 198 $ 198 $ 395 $ 396 Capitalized interest (7 ) (50 ) (54 ) (97 ) Total interest expense, net $ 191 $ 148 $ 341 $ 299
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount, which is net of unamortized premium, discount and debt issuance costs, and estimated fair value of our debt (in millions): June 30, 2019 December 31, 2018 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes (1) $ 12,721 $ 14,041 $ 12,709 $ 13,235 2037 Senior Notes (2) 791 912 791 817 (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)

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned from contracts with customers during the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 LNG revenues $ 1,171 $ 1,155 $ 2,537 $ 2,170 LNG revenues—affiliate 455 178 760 681 Total revenues from customers 1,626 1,333 3,297 2,851 Net derivative gains (1) — — 1 — Total revenues $ 1,626 $ 1,333 $ 3,298 $ 2,851 (1) See Note 6—Derivative Instruments for additional information about our derivatives.
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenues on our Balance Sheets (in millions): Six Months Ended June 30, 2019 Deferred revenues, beginning of period $ 91 Cash received but not yet recognized 101 Revenue recognized from prior period deferral (91 ) Deferred revenues, end of period $ 101
Transaction Price Allocated to Future Performance Obligations	The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Weighted Average Recognition Timing (years) (1) LNG revenues (2) $ 56.3 10 $ 53.6 10 (1) The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price. (2) Includes future consideration from agreement anticipated to be assigned to SPL from Cheniere Marketing.

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Income for the three and six months ended June 30, 2019 and 2018 (in millions): Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 LNG revenues—affiliate Cheniere Marketing Agreements $ 455 $ 178 $ 760 $ 681 Cost of sales—affiliate Cargo loading fees under TUA 9 7 18 15 Operating and maintenance expense—affiliate TUA 67 64 131 128 Natural Gas Transportation Agreement 21 21 40 41 Services Agreements 27 22 51 41 Total operating and maintenance expense—affiliate 115 107 222 210 General and administrative expense—affiliate Services Agreements 21 12 36 24

Customer Concentration (Tables)

Customer Concentration (Tables)	6 Months Ended
	Jun. 30, 2019
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 revenues from external customers and customers with accounts receivable balances of 10% or greater of total accounts receivable from external customers: Percentage of Total Revenues from External Customers Percentage of Accounts Receivable from External Customers Three Months Ended June 30, Six Months Ended June 30, June 30, December 31, 2019 2018 2019 2018 2019 2018 Customer A 32% 28% 32% 31% 19% 35% Customer B 21% 23% 21% 25% 26% 23% Customer C 21% 24% 20% 25% 26% 30% Customer D 24% 21% 24% 16% 26% * * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Six Months Ended June 30, 2019 2018 Cash paid during the period for interest, net of amounts capitalized $ 282 $ 285 Non-cash distributions to affiliates for conveyance of assets 348 —

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)trains	Jan. 01, 2019USD ($)	Dec. 31, 2018USD ($)
Nature of Operations and Basis of Presentation [Line Items]
Income Tax Expense	$ 0
Other non-current assets, net	153		$ 158
Other non-current liabilities	7		3
Other non-current liabilities—affiliate	$ 16		$ 0
Accounting Standards Update 2016-02 [Member]
Nature of Operations and Basis of Presentation [Line Items]
Other non-current assets, net		$ 20
Other non-current liabilities		4
Other non-current liabilities—affiliate		$ 16
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, 2019	Dec. 31, 2018
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 596	$ 756
Liquefaction Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 596	$ 756

Accounts and Other Receivable_2

Accounts and Other Receivables (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Receivables [Abstract]
Trade receivable	$ 234	$ 330
Other accounts receivable	6	16
Total accounts and other receivables	$ 240	$ 346

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Inventory [Line Items]
Inventory	$ 91	$ 87
Natural gas [Member]
Inventory [Line Items]
Inventory	15	28
LNG [Member]
Inventory [Line Items]
Inventory	9	6
Materials and other [Member]
Inventory [Line Items]
Inventory	$ 67	$ 53

Property, Plant and Equipment -

Property, Plant and Equipment - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Depreciation expense	$ 118	$ 85	$ 212	$ 169
Offsets to LNG terminal costs	$ 0	$ 0	$ 48	$ 0

Property, Plant and Equipment_2

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 13,722	$ 13,209
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(875)	(667)
Property, plant and equipment, net	13,716	13,203
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,644	10,004
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	947	3,866
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16	14
Accumulated depreciation	(10)	(8)
Property, plant and equipment, net	$ 6	$ 6

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - tbtu	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Energy Units Secured Through Natural Gas Supply Contracts	3,437	3,464
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	5 years
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount	3,122	2,978

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 34	$ (43)
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	1	5
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(1)	(23)
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	$ 34	$ (25)

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member]	6 Months Ended
	Jun. 30, 2019USD ($)
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset	$ 34,000,000
Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	(0.350)
Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	$ 0.056

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, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period	$ 29	$ 10	$ (25)	$ 43
Realized and mark-to-market gains (losses):
Included in cost of sales	3	(1)	16	(13)
Purchases and settlements:
Purchases	1	6	0	6
Settlements	1	(4)	43	(25)
Balance, end of period	34	11	34	11
Change in unrealized gains (losses) relating to instruments still held at end of period	$ 3	$ (1)	$ 16	$ (13)

Derivative Instruments - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative assets		$ 17	$ 6
Non-current derivative assets		37	31
Derivative liabilities		(8)	(66)
Non-current derivative liabilities		(12)	(14)
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	54	37
Total derivative liabilities	[1]	(20)	(80)
Derivative asset (liability), net	[1]	34	(43)
Derivative, collateral call		2	1
Liquefaction Supply Derivatives [Member] | Derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	17	6
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	[1]	37	31
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	(8)	(66)
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	[1]	$ (12)	$ (14)
[1]	Does not include collateral calls of $2 million and $1 million for such contracts, which are included in other current assets in our Balance Sheets as of June 30, 2019 and December 31, 2018

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
LNG revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 0	$ 0	$ 1	$ 0
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 7	$ (2)	$ 83	$ (52)
[1]	Does not include the realized value associated with derivative instruments that settle through physical delivery. 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 - Deri_2

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 56	$ 63
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(2)	(26)
Net Amounts Presented in our Balance Sheets	54	37
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(21)	(92)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	1	12
Net Amounts Presented in our Balance Sheets	$ (20)	$ (80)

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Other Assets, Noncurrent [Abstract]
Advances made to municipalities for water system enhancements	$ 89	$ 90
Advances and other asset conveyances to third parties to support LNG terminals	36	36
Operating lease assets	21	0
Information technology service assets	7	16
Advances made under EPC and non-EPC contracts	0	14
Other	0	2
Other non-current assets, net	$ 153	$ 158

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 230	$ 186
Accrued natural gas purchases	310	518
Liquefaction Project costs	469	64
Other accrued liabilities	2	0
Total accrued liabilities	$ 1,011	$ 768

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Unamortized discount, premium and debt issuance costs, net	$ (138,000,000)	$ (150,000,000)
Long-term Debt, Net	13,512,000,000	13,500,000,000
Current Debt, Working Capital Facility	0	0
Total Debt, Net	13,512,000,000	13,500,000,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 2,000,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 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, Gross	$ 1,500,000,000	1,500,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 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, Gross	$ 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, Gross	$ 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, Gross	$ 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, Gross	$ 1,350,000,000	1,350,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.20%
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 800,000,000	800,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Working Capital Facility [Member]
Debt Instrument [Line Items]
Current Debt, Working Capital Facility	$ 0	$ 0
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,200,000,000

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Outstanding balance	$ 0	$ 0
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	1,200
Outstanding balance	0	$ 0
Letters of credit issued	415
Available commitment	$ 785
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Debt Instrument, Maturity Date	Dec. 31, 2020
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, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Debt Disclosure [Abstract]
Total interest cost	$ 198	$ 198	$ 395	$ 396
Capitalized interest	(7)	(50)	(54)	(97)
Total interest expense, net	$ 191	$ 148	$ 341	$ 299

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Jun. 30, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 13,512	$ 13,500
Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	12,721	12,709
Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	14,041	13,235
2037 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	791	791
2037 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	$ 912	$ 817
[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.

Revenues from Contracts with _3

Revenues from Contracts with Customers - Narrative (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	53.00%	55.00%	55.00%	55.00%
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	100.00%	100.00%	100.00%	100.00%

Revenues from Contracts with _4

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 1,626	$ 1,333	$ 3,297	$ 2,851
Revenues	1,626	1,333	3,298	2,851
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,171	1,155	2,537	2,170
Revenues	1,171	1,155	2,538	2,170
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	455	178	760	681
Gains from derivative instruments [Member]
Disaggregation of Revenue [Line Items]
Revenues	$ 0	$ 0	$ 1	$ 0

Revenues from Contracts with _5

Revenues from Contracts with Customers - Schedule of Deferred Revenue Reconciliation (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenues, beginning of period	$ 91
Cash received but not yet recognized	101
Revenue recognized from prior period deferral	(91)
Deferred revenues, end of period	$ 101

Revenues from Contracts with _6

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - LNG [Member] - USD ($) $ in Billions		Jun. 30, 2019	Dec. 31, 2018
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price	[1]	$ 56.3	$ 53.6
Weighted Average Recognition Timing	[1],[2]	10 years	10 years
[1]	Includes future consideration from agreement anticipated to be assigned to SPL from Cheniere Marketing.
[2]	The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Related Party Transaction [Line Items]
Cost of sales—affiliate	$ 9	$ 7	$ 18	$ 15
Operating and maintenance expense—affiliate	115	107	222	210
General and administrative expense—affiliate	21	12	36	24
Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	455	178	760	681
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	9	7	18	15
Operating and maintenance expense—affiliate	67	64	131	128
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	21	21	40	41
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	27	22	51	41
General and administrative expense—affiliate	$ 21	$ 12	$ 36	$ 24

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) MMBTU in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2019MMBTUCargo$ / MMBTU	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)bcf / ditem$ / MMBTU	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Related Party Transaction [Line Items]
Accounts receivable—affiliate		$ 166,000,000		$ 166,000,000		$ 113,000,000
Advances to affiliate		206,000,000		$ 206,000,000		210,000,000
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
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
Letter Agreement [Member] | Cheniere Marketing [Member]
Related Party Transaction [Line Items]
Contract Volumes | MMBTU	70
LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
LNG Volume, Purchase Price | $ / MMBTU	2
Letter Agreement [Member] | Cheniere Marketing [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	20
Natural Gas Transportation Agreement [Member] | CTPL [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term				20 years
Related Party Agreement, Termination Notice Period				1 year
Related Party Agreement, Number Of Available Extensions | item				2
Related Party Agreement, Term Of Available Extension				10 years
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate		206,000,000		$ 206,000,000		$ 210,000,000
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		$ 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
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment				$ 1,000,000
Term of available extension		10 years		10 years
Review Period for Inflation Adjustment				5 years
Cooperation Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement		$ 348,000,000	$ 0	$ 348,000,000	$ 0
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, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	32.00%	28.00%	32.00%	31.00%
Customer A [Member] | Accounts Receivable from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			19.00%		35.00%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	21.00%	23.00%	21.00%	25.00%
Customer B [Member] | Accounts Receivable from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			26.00%		23.00%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	21.00%	24.00%	20.00%	25.00%
Customer C [Member] | Accounts Receivable from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			26.00%		30.00%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	24.00%	21.00%	24.00%	16.00%
Customer D [Member] | Accounts Receivable from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			26.00%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 282	$ 285
Non-cash distributions to affiliates for conveyance of assets	348	0
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$ 683	$ 249