Cheniere Energy Partners (CQP) 10-Q 8 Nov 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Nov. 02, 2018
Entity Information [Line Items]
Entity Registrant Name	Cheniere Energy Partners, L.P.
Entity Central Index Key	1,383,650
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Small Business	false
Entity Emerging Growth Company	false
Common Units [Member]
Entity Information [Line Items]
Entity Units, Units Outstanding		348,623,792
Subordinated Units [Member]
Entity Information [Line Items]
Entity Units, Units Outstanding		135,383,831

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 0	$ 0
Restricted cash	1,457	1,589
Accounts and other receivables	224	191
Accounts receivable—affiliate	22	163
Advances to affiliate	189	36
Inventory	88	95
Other current assets	55	65
Total current assets	2,035	2,139
Property, plant and equipment, net	15,282	15,139
Debt issuance costs, net	15	38
Non-current derivative assets	25	31
Other non-current assets, net	179	206
Total assets	17,536	17,553
Current liabilities
Accounts payable	13	12
Accrued liabilities	503	637
Due to affiliates	53	68
Deferred revenue	119	111
Deferred revenue—affiliate	0	1
Derivative liabilities	6	0
Total current liabilities	694	829
Long-term debt, net	16,059	16,046
Non-current derivative liabilities	2	3
Other non-current liabilities	10	11
Other non-current liabilities—affiliate	23	25
Partners’ equity
Common unitholders’ interest (348.6 million units issued and outstanding at September 30, 2018 and December 31, 2017)	1,759	1,670
Subordinated unitholders’ interest (135.4 million units issued and outstanding at September 30, 2018 and December 31, 2017)	(1,008)	(1,043)
General partner’s interest (2% interest with 9.9 million units issued and outstanding at September 30, 2018 and December 31, 2017)	(3)	12
Total partners’ equity	748	639
Total liabilities and partners’ equity	$ 17,536	$ 17,553

Consolidated Balance Sheets Par

Consolidated Balance Sheets Parentheticals - shares shares in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
General Partner Ownership Interest Percentage	2.00%	2.00%
General Partners' Capital Account, Units Issued	9.9	9.9
General Partners' Capital Account, Units Outstanding	9.9	9.9
Common Units [Member]
Limited Partners' Capital Account, Units Issued	348.6	348.6
Limited Partners' Capital Account, Units Outstanding	348.6	348.6
Subordinated Units [Member]
Limited Partners' Capital Account, Units Issued	135.4	135.4
Limited Partners' Capital Account, Units Outstanding	135.4	135.4

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues
Revenue earned from contracts with customers	$ 1,465	$ 897	$ 4,412	$ 2,763
Revenues	1,529	903	4,529	2,786
Operating costs and expenses
Cost of sales (excluding depreciation and amortization expense shown separately below)	756	490	2,291	1,580
Operating and maintenance expense	113	73	306	205
Operating and maintenance expense—affiliate	31	31	87	70
Development expense	1	1	2	2
General and administrative expense	3	5	9	10
General and administrative expense—affiliate	18	18	53	63
Depreciation and amortization expense	107	87	318	239
Impairment expense and loss on disposal of assets	8	0	8	0
Other	0	1	0	1
Total operating costs and expenses	1,037	706	3,074	2,170
Income (loss) from operations	492	197	1,455	616
Other income (expense)
Interest expense, net of capitalized interest	(183)	(153)	(552)	(437)
Loss on modification or extinguishment of debt	(12)	(25)	(12)	(67)
Derivative gain (loss), net	2	1	13	(2)
Other income	8	3	19	6
Total other income (expense)	(185)	(174)	(532)	(500)
Net income (loss)	$ 307	$ 23	$ 923	$ 116
Basic and diluted net income (loss) per common unit	$ 0.60	$ (1.10)	$ 1.82	$ (4.12)
Weighted average number of common units outstanding used for basic and diluted net income (loss) per common unit calculation	348.6	247.2	348.6	121.2
LNG [Member]
Revenues
Revenue earned from contracts with customers	$ 1,185	$ 717	$ 3,302	$ 1,695
Revenues	1,249	723	3,419	1,718
LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	205	111	886	864
Regasification [Member]
Revenues
Revenue earned from contracts with customers	66	65	196	195
Other [Member]
Revenues
Revenue earned from contracts with customers	9	3	28	7
Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	$ 0	$ 1	$ 0	$ 2

Consolidated Statement of Partn

Consolidated Statement of Partners' Equity - 9 months ended Sep. 30, 2018 - USD ($) shares in Millions, $ in Millions	Total	Common Units [Member]	Subordinated Units [Member]	General Partner [Member]
Units, Outstanding, beginning of period at Dec. 31, 2017		348.6	135.4
Partners' equity, beginning of period at Dec. 31, 2017	$ 639	$ 1,670	$ (1,043)	$ 12
General partner units, Outstanding, beginning of period at Dec. 31, 2017	9.9			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	$ 923	651	253	$ 19
Distributions	(814)	$ (562)	$ (218)	(34)
Units, Outstanding, end of period at Sep. 30, 2018		348.6	135.4
Partners' equity, end of period at Sep. 30, 2018	$ 748	$ 1,759	$ (1,008)	$ (3)
General partner units, Outstanding, end of period at Sep. 30, 2018	9.9			9.9

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash flows from operating activities
Net income	$ 923	$ 116
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	318	239
Amortization of debt issuance costs, deferred commitment fees, premium and discount	24	28
Loss on modification or extinguishment of debt	12	67
Total losses on derivatives, net	29	53
Net cash used for settlement of derivative instruments	0	(15)
Impairment expense and loss on disposal of assets	8	0
Other	5	1
Changes in operating assets and liabilities:
Accounts and other receivables	(33)	(69)
Accounts receivable—affiliate	140	82
Advances to affiliate	(79)	(36)
Inventory	6	28
Accounts payable and accrued liabilities	(77)	19
Due to affiliates	(5)	(47)
Deferred revenue	6	58
Other, net	(10)	(9)
Other, net—affiliate	(3)	(2)
Net cash provided by operating activities	1,264	513
Cash flows from investing activities
Property, plant and equipment, net	(578)	(1,195)
Net cash provided by (used in) investing activities	(578)	(1,195)
Cash flows from financing activities
Proceeds from issuances of debt	1,100	3,814
Repayments of debt	(1,090)	(2,173)
Debt issuance and deferred financing costs	(8)	(47)
Debt extinguishment costs	(6)	0
Distributions to owners	(814)	(74)
Net cash provided by (used in) financing activities	(818)	1,520
Net increase (decrease) in cash, cash equivalents and restricted cash	(132)	838
Cash, cash equivalents and restricted cash—beginning of period	1,589	605
Cash, cash equivalents and restricted cash—end of period	$ 1,457	$ 1,443

Consolidated Statements of Ca_2

Consolidated Statements of Cash Flows - Balances per Consolidated Balance Sheet - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	$ 0	$ 0
Restricted cash	1,457	1,589
Total cash, cash equivalents and restricted cash	$ 1,457	$ 1,589	$ 1,443	$ 605

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION T hrough SPL, we are developing, constructing and operating natural gas liquefaction facilities (the “Liquefaction Project”) at the Sab ine Pass LNG terminal located in Cameron Parish, Louisiana, 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 4 are operational, Train 5 is undergoing commissioning and Train 6 is being commercialized and has all necessary regulatory approvals in place. The Sabine Pass LNG terminal has operational regasification facilities owned by SPLNG and a 94 -mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) through CTPL. Basis of Presentation The accompanying unaudited Consolidated Financial Statements of Cheniere Partners 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 Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2017 . 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 did not have a material effect on our consolidated financial position, results of operations or cash flows. On January 1, 2018, we adopted ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto (“ASC 606”) using the full retrospective method. The adoption of ASC 606 represents a change in accounting principle that will provide financial statement readers with enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of ASC 606 did not impact our previously reported consolidated financial statements in any prior period nor did it result in a cumulative effect adjustment to retained earnings. Results of operations for the three and nine months ended September 30, 2018 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2018 . We are not subject to either federal or state income tax, as our partners are taxed individually on their allocable share of our taxable income.

Unitholders' Equity

Unitholders' Equity	9 Months Ended
	Sep. 30, 2018
Partners' Capital Notes [Abstract]
Unitholders' Equity	UNITHOLDERS’ EQUITY The common units and subordinated units represent limited partner interests in us. The holders of the units are entitled to participate in partnership distributions and exercise the rights and privileges available to limited partners under our partnership agreement. Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash (as defined in our partnership agreement). Generally, our available cash is our cash on hand at the end of a quarter less the amount of any reserves established by our general partner. All distributions paid to date have been made from operating surplus as defined in the partnership agreement. The holders of common units have the right to receive initial quarterly distributions of $0.425 per common unit, plus any arrearages thereon, before any distribution is made to the holders of the subordinated units. The holders of subordinated units will receive distributions only to the extent we have available cash above the initial quarterly distribution requirement for our common unitholders and general partner and certain reserves. Subordinated units will convert into common units on a one-for-one basis when we meet financial tests specified in the partnership agreement. Although common and subordinated unitholders are not obligated to fund losses of the Partnership, their capital accounts, which would be considered in allocating the net assets of the Partnership were it to be liquidated, continue to share in losses. The general partner interest is entitled to at least 2% of all distributions made by us. In addition, the general partner holds incentive distribution rights (“IDRs”) , which allow the general partner to receive a higher percentage of quarterly distributions of available cash from operating surplus after the initial quarterly distributions have been achieved and as additional target levels are met, but may transfer these rights separately from its general partner interest. The higher percentages range from 15% to 50% , inclusive of the general partner interest. During the three months ended September 30, 2018, Cheniere Energy Partners LP Holdings, LLC (“Cheniere Holdings”), which holds limited partner interests in us, merged with a wholly owned subsidiary of Cheniere. As of September 30, 2018 , Cheniere, Blackstone CQP Holdco and the public own a 48.6% , 40.3% and 9.1% interest in us, respectively. Cheniere’s ownership percentage includes its subordinated units and Blackstone CQP Holdco ’s ownership percentage excludes any common units that may be deemed to be beneficially owned by Blackstone Group, an affiliate of Blackstone CQP Holdco .

Restricted Cash

Restricted Cash	9 Months Ended
	Sep. 30, 2018
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 Consolidated Balance Sheets. As of September 30, 2018 and December 31, 2017 , restricted cash consisted of the following (in millions): September 30, December 31, 2018 2017 Current restricted cash Liquefaction Project $ 649 $ 544 Cash held by us and our guarantor subsidiaries 808 1,045 Total current restricted cash $ 1,457 $ 1,589 Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of SPL’s debt holders, SPL is 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. Under our credit facilities (the “CQP Credit Facilities”) , we and each of our subsidiaries other than SPL, as our guarantor subsidiaries, are subject to limitations on the use of cash under the terms of the CQP Credit Facilities and the related depositary agreement governing the extension of credit to us. Specifically, we may only withdraw funds from collateral accounts held at a designated depositary bank on a limited basis and for specific purposes, including for the payment of our operating expenses and the operating expenses of our guarantor subsidiaries. In addition, distributions and capital expenditures may only be made quarterly and are subject to certain restrictions.

Accounts and Other Receivables

Accounts and Other Receivables	9 Months Ended
	Sep. 30, 2018
Receivables [Abstract]
Accounts and Other Receivables	ACCOUNTS AND OTHER RECEIVABLES As of September 30, 2018 and December 31, 2017 , accounts and other receivables consisted of the following (in millions): September 30, December 31, 2018 2017 SPL trade receivable $ 213 $ 185 Other accounts receivable 11 6 Total accounts and other receivables $ 224 $ 191

Inventory

Inventory	9 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of September 30, 2018 and December 31, 2017 , inventory consisted of the following (in millions): September 30, December 31, 2018 2017 Natural gas $ 9 $ 17 LNG 21 26 Materials and other 58 52 Total inventory $ 88 $ 95

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT As of September 30, 2018 and December 31, 2017 , property, plant and equipment, net consisted of the following (in millions): September 30, December 31, 2018 2017 LNG terminal costs LNG terminal and interconnecting pipeline facilities $ 12,706 $ 12,703 LNG terminal construction-in-process 3,757 3,310 Accumulated depreciation (1,187 ) (880 ) Total LNG terminal costs, net 15,276 15,133 Fixed assets Fixed assets 26 23 Accumulated depreciation (20 ) (17 ) Total fixed assets, net 6 6 Property, plant and equipment, net $ 15,282 $ 15,139 Depreciation expense was $104 million and $85 million during the three months ended September 30, 2018 and 2017 , respectively, and $310 million and $233 million during the nine months ended September 30, 2018 and 2017 , respectively. We realized offsets to LNG terminal costs of $79 million and $242 million in the three and nine months ended September 30, 2017 , 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. We did no t realize any offsets to LNG terminal costs in the three and nine months ended September 30, 2018 .

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2018
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 certain 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”) . 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 Consolidated 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 September 30, 2018 and December 31, 2017 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in millions). Fair Value Measurements as of September 30, 2018 December 31, 2017 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 CQP Interest Rate Derivatives asset $ — $ 28 $ — $ 28 $ — $ 21 $ — $ 21 Liquefaction Supply Derivatives asset (liability) (1 ) 1 19 19 2 10 43 55 There have been no changes to our evaluation of and accounting for our derivative positions during the nine months ended September 30, 2018 . See Note 8—Derivative Instruments of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, 2017 for additional information. We value our Interest Rate Derivatives using an income-based approach, utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. 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 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. 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 September 30, 2018 : Net Fair Value Asset (in millions) Valuation Approach Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $19 Market approach incorporating present value techniques Basis Spread $(0.448) - $0.079 The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Balance, beginning of period $ 11 $ 40 $ 43 $ 79 Realized and mark-to-market gains (losses): Included in cost of sales 4 (8 ) (5 ) (43 ) Purchases and settlements: Purchases 4 (1 ) 8 1 Settlements 1 (2 ) (27 ) (8 ) Transfers out of Level 3 (1) (1 ) — — — Balance, end of period $ 19 $ 29 $ 19 $ 29 Change in unrealized gains relating to instruments still held at end of period $ 4 $ (8 ) $ (5 ) $ (43 ) (1) Transferred to Level 2 as a result of observable market for the underlying natural gas purchase agreements. 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. Additionally, we evaluate our own ability to meet our commitments in instances where our derivative instruments are in a liability 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 swaps (“CQP Interest Rate Derivatives”) to hedge a portion of the variable interest payments on the CQP Credit Facilities , based on a portion of the expected outstanding borrowings over the term of the CQP Credit Facilities . In September 2018, we terminated approximately $1.2 billion of commitments under the CQP Credit Facilities , as discussed in Note 10—Debt . In October 2018, we terminated the CQP Interest Rate Derivatives related to the CQP Credit Facilities , which resulted in a derivative gain of $28 million . SPL had entered into interest rate swaps (“SPL Interest Rate Derivatives”) to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the credit facilities it entered into in June 2015 (the “SPL Credit Facilities”) , based on a portion of the expected outstanding borrowings over the term of the SPL Credit Facilities. In March 2017, SPL settled the SPL 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 SPL Credit Facilities . As of September 30, 2018 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received CQP Interest Rate Derivatives $225 million $1.3 billion March 22, 2016 February 29, 2020 1.19% One-month LIBOR The following table shows the fair value and location of the CQP Interest Rate Derivatives on our Consolidated Balance Sheets (in millions): September 30, December 31, Consolidated Balance Sheet Location 2018 2017 Other current assets $ 19 $ 7 Non-current derivative assets 9 14 Total derivative assets $ 28 $ 21 The following table shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Income during the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 CQP Interest Rate Derivatives gain $ 2 $ 1 $ 13 $ — SPL Interest Rate Derivatives loss — — — (2 ) Liquefaction Supply Derivatives SPL has entered into index-based physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the Liquefaction Project. The terms of the physical natural gas supply contracts range up to six years, some of which commence upon the satisfaction of certain conditions precedent. SPL had secured up to approximately 2,755 TBtu and 2,214 TBtu of natural gas feedstock through natural gas supply contracts as of September 30, 2018 and December 31, 2017 , respectively. The notional natural gas position of our Liquefaction Supply Derivatives was approximately 2,206 TBtu and 1,520 TBtu as of September 30, 2018 and December 31, 2017 , respectively. The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Consolidated Balance Sheets (in millions): Fair Value Measurements as of (1) Consolidated Balance Sheet Location September 30, 2018 December 31, 2017 Other current assets $ 11 $ 41 Non-current derivative assets 16 17 Total derivative assets 27 58 Derivative liabilities (6 ) — Non-current derivative liabilities (2 ) (3 ) Total derivative liabilities (8 ) (3 ) Derivative asset, net $ 19 $ 55 (1) Does not include collateral calls of $2 million and $1 million as of September 30, 2018 and December 31, 2017 , respectively, for such contracts, which are included in other current assets in our Consolidated Balance Sheets. The following table shows the changes in the fair value and settlements of our Liquefaction Supply Derivatives recorded in cost of sales on our Consolidated Statements of Income during the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Liquefaction Supply Derivatives gain (loss) (1) $ 10 $ (11 ) $ (42 ) $ (51 ) (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. Consolidated Balance Sheet Presentation Our derivative instruments are presented on a net basis on our Consolidated 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 Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets Offsetting Derivative Assets (Liabilities) As of September 30, 2018 CQP Interest Rate Derivatives $ 28 $ — $ 28 Liquefaction Supply Derivatives 31 (4 ) 27 Liquefaction Supply Derivatives (13 ) 5 (8 ) As of December 31, 2017 CQP Interest Rate Derivatives $ 21 $ — $ 21 Liquefaction Supply Derivatives 64 (6 ) 58 Liquefaction Supply Derivatives (3 ) — (3 )

Other Non-Current Assets

Other Non-Current Assets	9 Months Ended
	Sep. 30, 2018
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS As of September 30, 2018 and December 31, 2017 , other non-current assets, net consisted of the following (in millions): September 30, December 31, 2018 2017 Advances made under EPC and non-EPC contracts $ 15 $ 26 Advances made to municipalities for water system enhancements 90 93 Advances and other asset conveyances to third parties to support LNG terminals 29 30 Tax-related payments and receivables 17 25 Information technology service assets 20 24 Other 8 8 Total other non-current assets, net $ 179 $ 206

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2018
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of September 30, 2018 and December 31, 2017 , accrued liabilities consisted of the following (in millions): September 30, December 31, 2018 2017 Interest costs and related debt fees $ 186 $ 253 Accrued natural gas purchases 249 298 LNG terminal and related pipeline costs 59 86 Other accrued liabilities 9 — Total accrued liabilities $ 503 $ 637

Debt

Debt	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Debt	DEBT As of September 30, 2018 and December 31, 2017 , our debt consisted of the following (in millions): September 30, December 31, 2018 2017 Long-term debt: SPL 5.625% Senior Secured Notes due 2021 (“2021 SPL Senior Notes”) $ 2,000 $ 2,000 6.25% Senior Secured Notes due 2022 (“2022 SPL Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 SPL Senior Notes”) 1,500 1,500 5.75% Senior Secured Notes due 2024 (“2024 SPL Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 SPL Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 SPL Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 SPL Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 SPL Senior Notes”) 1,350 1,350 5.00% Senior Secured Notes due 2037 (“2037 SPL Senior Notes”) 800 800 Cheniere Partners 5.250% Senior Notes due 2025 (“2025 CQP Senior Notes”) 1,500 1,500 5.625% Senior Notes due 2026 (“2026 CQP Senior Notes”) 1,100 — CQP Credit Facilities — 1,090 Unamortized premium, discount and debt issuance costs, net (191 ) (194 ) Total long-term debt, net 16,059 16,046 Current debt: $1.2 billion SPL Working Capital Facility (“SPL Working Capital Facility”) — — Total debt, net $ 16,059 $ 16,046 2018 Debt Issuances and Redemptions 2026 CQP Senior Notes In September 2018, we issued an aggregate principal amount of $1.1 billion of the 2026 CQP Senior Notes , which are jointly and severally guaranteed by each of our subsidiaries other than SPL (the “Guarantors”) and, subject to certain conditions governing its guarantee, Sabine Pass LP. Net proceeds of the offering of approximately $1.1 billion , after deducting the initial purchasers’ commissions and estimated fees and expenses, were used to prepay all of the outstanding indebtedness under the CQP Credit Facilities , resulting in the recognition of debt modification and extinguishment costs of $12 million for the three and nine months ended September 30, 2018 relating to the incurrence of third party fees and write off of unamortized debt issuance costs. As of September 30, 2018 , only a $115 million revolving credit facility, all of which is undrawn, remains as part of the CQP Credit Facilities . Borrowings under the 2026 CQP Senior Notes accrue interest at a fixed rate of 5.625% , and interest on the 2026 CQP Senior Notes is payable semi-annually in arrears. The 2026 CQP Senior Notes are governed by the same base indenture as the 2025 CQP Senior Notes (the “CQP Base Indenture”) , and are further governed by the Second Supplemental Indenture (together with the CQP Base Indenture, the “2026 CQP Notes Indenture”), which contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of the Guarantors to incur liens and sell assets, enter into transactions with affiliates, enter into sale-leaseback transactions and consolidate, merge or sell, lease or otherwise dispose of all or substantially all of the applicable entity’s properties or assets. At any time prior to October 1, 2021, we may redeem all or a part of the 2026 CQP Senior Notes at a redemption price equal to 100% of the aggregate principal amount of the 2026 CQP Senior Notes redeemed, plus the “applicable premium” set forth in the 2026 CQP Notes Indenture, plus accrued and unpaid interest, if any, to the date of redemption. In addition, at any time prior to October 1, 2021, we may redeem up to 35% of the aggregate principal amount of the 2026 CQP Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 105.625% of the aggregate principal amount of the 2026 CQP Senior Notes redeemed, plus accrued and unpaid interest, if any, to the date of redemption. At any time on or after October 1, 2021 through the maturity date of October 1, 2026, we may redeem the 2026 CQP Senior Notes , in whole or in part, at the redemption prices set forth in the 2026 CQP Notes Indenture. The 2026 CQP Senior Notes are our senior obligations, ranking equally in right of payment with our other existing and future unsubordinated debt and senior to any of our future subordinated debt. After applying the proceeds from the 2026 CQP Senior Notes , the 2026 CQP Senior Notes and the 2025 CQP Senior Notes (collectively, the “CQP Senior Notes”) became unsecured. In the event that the aggregate amount of our secured indebtedness and the secured indebtedness of the Guarantors (other than the CQP Senior Notes or any other series of notes issued under the CQP Base Indenture ) outstanding at any one time exceeds the greater of (1) $1.5 billion and (2) 10% of net tangible assets, the CQP Senior Notes will be secured to the same extent as such obligations under the CQP Credit Facilities . The obligations under the CQP Credit Facilities are secured on a first-priority basis (subject to permitted encumbrances) with liens on (1) substantially all the existing and future tangible and intangible assets and our rights and the rights of the Guarantors and equity interests in the Guarantors (except, in each case, for certain excluded properties set forth in the CQP Credit Facilities ) and (2) substantially all of the real property of SPLNG (except for excluded properties referenced in the CQP Credit Facilities ). In connection with the closing of the 2026 CQP Senior Notes offering, we and the Guarantors entered into a registration rights agreement (the “CQP Registration Rights Agreement”) . Under the CQP Registration Rights Agreement , we and the Guarantors have agreed to file with the SEC and cause to become effective a registration statement relating to an offer to exchange any and all of the 2026 CQP Senior Notes for a like aggregate principal amount of our debt securities with terms identical in all material respects to the 2026 CQP Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), within 360 days after the notes issuance date of September 11, 2018. Under specified circumstances, we and the Guarantors have also agreed to cause to become effective a shelf registration statement relating to resales of the 2026 CQP Senior Notes . We will be obligated to pay additional interest on the 2026 CQP Senior Notes if we fail to comply with our obligation to register the 2026 CQP Senior Notes within the specified time period. Credit Facilities Below is a summary of our credit facilities outstanding as of September 30, 2018 (in millions): SPL Working Capital Facility CQP Credit Facilities Original facility size $ 1,200 $ 2,800 Less: Outstanding balance — — Commitments prepaid or terminated — 2,685 Letters of credit issued 494 — Available commitment $ 706 $ 115 Interest rate LIBOR plus 1.75% or base rate plus 0.75% LIBOR plus 2.25% or base rate plus 1.25% (1) Maturity date December 31, 2020, with various terms for underlying loans February 25, 2020 (1) There is a 0.50% step-up for both LIBOR and base rate loans beginning on February 25, 2019. Restrictive Debt Covenants As of September 30, 2018 , we and SPL were in compliance with all covenants related to our respective debt agreements. Interest Expense Total interest expense consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total interest cost $ 235 $ 227 $ 701 $ 662 Capitalized interest (52 ) (74 ) (149 ) (225 ) Total interest expense, net $ 183 $ 153 $ 552 $ 437 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): September 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes (1) $ 15,268 $ 16,098 $ 14,166 $ 15,485 2037 SPL Senior Notes (2) 791 831 790 871 Credit facilities (3) — — 1,090 1,090 (1) Includes 2021 SPL Senior Notes , 2022 SPL Senior Notes , 2023 SPL Senior Notes , 2024 SPL Senior Notes , 2025 SPL Senior Notes , 2026 SPL Senior Notes , 2027 SPL Senior Notes , 2028 SPL Senior Notes , 2025 CQP Senior Notes and 2026 CQP 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 our stock price and 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 SPL Working Capital Facility and CQP Credit Facilities . 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.

Revenues from Contracts with Cu

Revenues from Contracts with Customers	9 Months Ended
	Sep. 30, 2018
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 nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 LNG revenues $ 1,185 $ 717 $ 3,302 $ 1,695 LNG revenues—affiliate 205 111 886 864 Regasification revenues 66 65 196 195 Other revenues 9 3 28 7 Other revenues—affiliate — 1 — 2 Total revenues from customers 1,465 897 4,412 2,763 Gains from derivative instruments (1) 64 6 117 23 Total revenues $ 1,529 $ 903 $ 4,529 $ 2,786 (1) Includes the realized value associated with a portion of derivative instruments that settle through physical delivery. LNG Revenues We have entered into numerous SPAs with third party customers for the sale of LNG on a free on board (“FOB”) (delivered to the customer at the Sabine Pass LNG terminal) basis. Our customers generally purchase LNG for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG equal to approximately 115% of Henry Hub. The fixed fee component is the amount payable to us regardless of a cancellation or suspension of LNG cargo deliveries by the customers. The variable fee component is the amount generally payable to us only upon delivery of LNG plus all future adjustments to the fixed fee for inflation. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery of a specified Train. Revenues from the sale of LNG are recognized at a point in time when the LNG is delivered to the customer, at the Sabine Pass LNG terminal, which is the point legal title, physical possession and the risks and rewards of ownership transfer to the customer. Each individual molecule of LNG is viewed as a separate performance obligation. The stated contract price (including both fixed and variable fees) per MMBtu in each LNG sales arrangement is representative of the stand-alone selling price for LNG at the time the sale was negotiated. We have concluded that the variable fees meet the exception for allocating variable consideration to specific parts of the contract. As such, the variable consideration for these contracts is allocated to each distinct molecule of LNG and recognized when that distinct molecule of LNG is delivered to the customer. Because of the use of the exception, variable consideration related to the sale of LNG is also not included in the transaction price. Fees received pursuant to SPAs are recognized as LNG revenues only after substantial completion of the respective Train. Prior to substantial completion, sales generated during the commissioning phase are offset against the cost of construction for the respective Train, as the production and removal of LNG from storage is necessary to test the facility and bring the asset to the condition necessary for its intended use. Regasification Revenues The Sabine Pass LNG terminal has operational regasification capacity of approximately 4.0 Bcf/d. Approximately 2.0 Bcf/d of the regasification capacity at the Sabine Pass LNG terminal has been reserved under two long-term TUAs with unaffiliated third-party customers, under which they are required to pay fixed monthly fees regardless of their use of the LNG terminal. Each of the customers has reserved approximately 1.0 Bcf/d of regasification capacity. The customers are each obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually for 20 years that commenced in 2009, which is representative of fixed consideration in the contract. A portion of this fee is adjusted annually for inflation which is considered variable consideration. The remaining capacity of the Sabine Pass LNG terminal has been reserved by SPL, for which the associated revenues are eliminated in consolidation. Because SPLNG is continuously available to provide regasification service on a daily basis with the same pattern of transfer, we have concluded that SPLNG provides a single performance obligation to its customers on a continuous basis over time. We have determined that an output method of recognition based on elapsed time best reflects the benefits of this service to the customer and accordingly, LNG regasification capacity reservation fees are recognized as regasification revenues on a straight-line basis over the term of the respective TUAs. We have concluded that the inflation element within the contract meets the exception for allocating variable consideration to specific parts of the contract and accordingly the inflation adjustment is not included in the transaction price and will be recognized over the year in which the inflation adjustment relates on a straight-line basis. In 2012, SPL entered into a partial TUA assignment agreement with Total Gas & Power North America, Inc. (“Total”) , whereby SPL would progressively gain access to Total ’s capacity and other services provided under its TUA with SPLNG. This agreement provides SPL with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to provide increased flexibility in managing LNG cargo loading and unloading activity, permit SPL to more flexibly manage its LNG storage capacity and accommodate the development of Trains 5 and 6. Upon substantial completion of Train 3 of the Liquefaction Project , SPL gained access to a portion of Total ’s capacity and other services provided under Total ’s TUA with SPLNG. Upon substantial completion of Train 5, SPL will gain access to substantially all of Total ’s capacity. Notwithstanding any arrangements between Total and SPL, payments required to be made by Total to SPLNG will continue to be made by Total to SPLNG in accordance with its TUA and we continue to recognize the payments received from Total as revenue. During each of the three months ended September 30, 2018 and 2017 , SPL recorded $7.5 million and during the nine months ended September 30, 2018 and 2017 , SPL recorded $23 million and $15 million , respectively, as operating and maintenance expense under this partial TUA assignment agreement. Deferred Revenue Reconciliation The following table reflects the changes in our contract liabilities, which we classify as deferred revenues on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2018 Deferred revenues, beginning of period $ 111 Cash received but not yet recognized 119 Revenue recognized from prior period deferral (111 ) Deferred revenues, end of period $ 119 We record deferred revenue when we receive consideration, or such consideration is unconditionally due from a customer, prior to transferring goods or services to the customer under the terms of a sales contract. Changes in deferred revenue during the nine months ended September 30, 2018 are primarily attributable to differences between the timing of revenue recognition and the receipt of advance payments related to delivery of LNG under certain SPAs. 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 September 30, 2018 : Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 54.2 10.2 Regasification revenues 2.7 5.8 Total revenues $ 56.9 (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. 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 all variable consideration under our SPAs and TUAs. 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. During each of the three and nine months ended September 30, 2018 , approximately 55% of our LNG revenues, 100% of our LNG revenues—affiliate and approximately 3% of our regasification revenues were related to variable consideration received from customers. 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. We have elected the practical expedient to omit the disclosure of the transaction price allocated to future performance obligations and an explanation of when the entity expects to recognize the amount as revenue as of December 31, 2017 .

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Consolidated Statements of Income for the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 205 $ 111 $ 886 $ 864 Other revenues—affiliate Terminal Marine Services Agreement — 1 — 2 Operating and maintenance expense—affiliate Services Agreements 31 25 87 64 Other agreements — 6 — 6 Total operating and maintenance expense—affiliate 31 31 87 70 General and administrative expense—affiliate Services Agreements 18 18 53 63 LNG Terminal Capacity Agreements Terminal Use Agreements SPL obtained approximately 2.0 Bcf/d of regasification capacity and other liquefaction support services under a TUA with SPLNG as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA with SPLNG. SPL is obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”) , continuing until at least May 2036. In connection with this TUA , SPL is required to pay for a portion of the cost (primarily LNG inventory) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal, which is recorded as operating and maintenance expense on our Consolidated Statements of Income . Cheniere Investments, SPL and SPLNG entered into the terminal use rights assignment and agreement (the “TURA”) pursuant to which Cheniere Investments had the right to use SPL’s reserved capacity under the TUA and had the obligation to pay the TUA Fees required by the TUA to SPLNG. However, the revenue earned by SPLNG from the TUA Fees and the loss incurred by Cheniere Investments under the TURA are eliminated upon consolidation of our Consolidated Financial Statements. We have guaranteed the obligations of SPL under its TUA and the obligations of Cheniere Investments under the TURA . In an effort to utilize Cheniere Investments’ reserved capacity under the TURA during construction of the Liquefaction Project , Cheniere Marketing has entered into an amended and restated variable capacity rights agreement with Cheniere Investments (the “Amended and Restated VCRA”) pursuant to which Cheniere Marketing is obligated to pay Cheniere Investments 80% of the expected gross margin of each cargo of LNG that Cheniere Marketing arranges for delivery to the Sabine Pass LNG terminal. Cheniere Investments recorded no revenues—affiliate from Cheniere Marketing during the three and nine months ended September 30, 2018 and 2017 related to the Amended and Restated VCRA . Cheniere Marketing SPA Cheniere Marketing has an SPA with SPL to purchase, at Cheniere Marketing’s option, any LNG produced by SPL 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 SPL has an agreement with Cheniere Marketing that allows the parties to sell and purchase LNG with each other by executing and delivering confirmations under this agreement. SPL executed a confirmation with Cheniere Marketing that obligates Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the period while Bechtel Oil, Gas and Chemicals, Inc. has control of, and is commissioning, Train 5 of the Liquefaction Project . Services Agreements As of September 30, 2018 and December 31, 2017 , we had $189 million and $36 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. Cheniere Partners Services Agreement We have a services agreement with Cheniere Terminals, a wholly owned subsidiary of Cheniere, pursuant to which Cheniere Terminals is entitled to a quarterly non-accountable overhead reimbursement charge of $3 million (adjusted for inflation) for the provision of various general and administrative services for our benefit. In addition, Cheniere Terminals is entitled to reimbursement for all audit, tax, legal and finance fees incurred by Cheniere Terminals that are necessary to perform the services under the agreement. Cheniere Investments Information Technology Services Agreement Cheniere Investments has an information technology services agreement with Cheniere, pursuant to which Cheniere Investments’ subsidiaries 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. SPLNG O&M Agreement SPLNG has a long-term operation and maintenance agreement (the “SPLNG O&M Agreement”) with Cheniere Investments pursuant to which SPLNG receives all necessary services required to operate and maintain the Sabine Pass LNG receiving terminal. SPLNG pays a fixed monthly fee of $130,000 (indexed for inflation) under the SPLNG O&M Agreement and the cost of a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between SPLNG and Cheniere Investments at the beginning of each operating year. In addition, SPLNG is required to reimburse Cheniere Investments for its operating expenses, which consist primarily of labor expenses. Cheniere Investments provides the services required under the SPLNG O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. All payments received by Cheniere Investments under the SPLNG O&M Agreement are required to be remitted to such subsidiary. SPLNG MSA SPLNG has a long-term management services agreement (the “SPLNG MSA”) with Cheniere Terminals, pursuant to which Cheniere Terminals manages the operation of the Sabine Pass LNG receiving terminal, excluding those matters provided for under the SPLNG O&M Agreement . SPLNG pays a monthly fixed fee of $520,000 (indexed for inflation) under the SPLNG MSA . SPL O&M Agreement SPL has an operation and maintenance agreement (the “SPL O&M Agreement”) with Cheniere Investments pursuant to which SPL receives 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 behalf of SPL, 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, SPL is 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, SPL 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. Cheniere Investments provides the services required under the SPL O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. All payments received by Cheniere Investments under the SPL O&M Agreement are required to be remitted to such subsidiary. SPL MSA SPL has a management services agreement (the “SPL 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 SPL O&M Agreement . The services include, among other services, exercising the day-to-day management of SPL’s affairs and business, managing SPL’s regulatory matters, managing bank and brokerage accounts and financial books and records of SPL’s business and operations, entering into financial derivatives on SPL’s 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 , SPL pays a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, SPL will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train. CTPL O&M Agreement CTPL has an amended long-term operation and maintenance agreement (the “CTPL O&M Agreement”) with Cheniere Investments pursuant to which CTPL receives all necessary services required to operate and maintain the Creole Trail Pipeline . CTPL is required to reimburse Cheniere Investments for its operating expenses, which consist primarily of labor expenses. Cheniere Investments provides the services required under the CTPL O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. All payments received by Cheniere Investments under the CTPL O&M Agreement are required to be remitted to such subsidiary. Agreement to Fund SPLNG’s Cooperative Endeavor Agreements SPLNG has executed Cooperative Endeavor Agreements (“CEAs”) with various Cameron Parish, Louisiana taxing authorities that allowed them to collect certain annual property tax payments from SPLNG from 2007 through 2016. This ten -year initiative represented an aggregate commitment of $25 million in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for SPLNG’s advance payments of annual ad valorem taxes, Cameron Parish will grant SPLNG a dollar-for-dollar credit against future ad valorem taxes to be levied against the Sabine Pass LNG terminal starting in 2019. Beginning in September 2007, SPLNG entered into various agreements with Cheniere Marketing, pursuant to which Cheniere Marketing would pay SPLNG additional TUA revenues equal to any and all amounts payable by SPLNG to the Cameron Parish taxing authorities under the CEAs . In exchange for such amounts received as TUA revenues from Cheniere Marketing, SPLNG will make payments to Cheniere Marketing equal to ad valorem tax levied on our LNG terminal in the year the Cameron Parish dollar-for-dollar credit is applied. On a consolidated basis, these advance tax payments were recorded to other non-current assets, and payments from Cheniere Marketing that SPLNG utilized to make the ad valorem tax payments were recorded as a long-term obligation. As of September 30, 2018 , we had $2 million in due to affiliates and $23 million of other non-current liabilities—affiliate resulting from these payments received from Cheniere Marketing. As of December 31, 2017 , we had $25 million of other non-current liabilities—affiliate resulting from these payments received from Cheniere Marketing. Contracts for Sale and Purchase of Natural Gas and LNG SPLNG is able to sell and purchase natural gas and LNG under agreements with Cheniere Marketing . Under these agreements, SPLNG purchases natural gas or LNG from Cheniere Marketing at a sales price equal to the actual purchase price paid by Cheniere Marketing to suppliers of the natural gas or LNG, plus any third-party costs incurred by Cheniere Marketing with respect to the receipt, purchase and delivery of natural gas or LNG to the Sabine Pass LNG terminal. Terminal Marine Services Agreement In connection with its tug boat lease, Tug Services entered into an agreement with a wholly owned subsidiary of Cheniere to provide its LNG cargo vessels with tug boat and marine services at the Sabine Pass LNG terminal. The agreement also provides that Tug Services shall contingently pay the wholly owned subsidiary of Cheniere a portion of its future revenues. Accordingly, Tug Services distributed $4 million to the wholly owned subsidiary of Cheniere during the nine months ended September 30, 2018 , which is reported as part of the distributions to our general partner interest holders on the Consolidated Statement of Partners’ Equity. No amounts were distributed during the nine months ended September 30, 2017 . LNG Terminal Export Agreement SPLNG and Cheniere Marketing have an LNG terminal export agreement that provides Cheniere Marketing the ability to export LNG from the Sabine Pass LNG terminal. SPLNG did no t record any revenues associated with this agreement during the three and nine months ended September 30, 2018 and 2017 . State Tax Sharing Agreements SPLNG has a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which SPLNG 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, SPLNG will pay to Cheniere an amount equal to the state and local tax that SPLNG would be required to pay if its 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 SPLNG under this agreement; therefore, Cheniere has not demanded any such payments from SPLNG. The agreement is effective for tax returns due on or after January 1, 2008. SPL has a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which SPL 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, SPL will pay to Cheniere an amount equal to the state and local tax that SPL would be required to pay if SPL’s 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 SPL under this agreement; therefore, Cheniere has not demanded any such payments from SPL. The agreement is effective for tax returns due on or after August 2012. CTPL has a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which CTPL 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, CTPL will pay to Cheniere an amount equal to the state and local tax that CTPL would be required to pay if CTPL’s 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 CTPL under this agreement; therefore, Cheniere has not demanded any such payments from CTPL. The agreement is effective for tax returns due on or after May 2013.

Net Income (Loss) per Common Un

Net Income (Loss) per Common Unit	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Net Income (Loss) per Common Unit	NET INCOME (LOSS) PER COMMON UNIT Net income (loss) per common unit for a given period is based on the distributions that will be made to the unitholders with respect to the period plus an allocation of undistributed net income (loss) based on provisions of the partnership agreement, divided by the weighted average number of common units outstanding. Distributions paid by us are presented on the Consolidated Statement of Partners’ Equity. On October 26, 2018 , we declared a $0.58 distribution per common unit and subordinated unit and the related distribution to our general partner and IDR holders to be paid on November 14, 2018 to unitholders of record as of November 5, 2018 for the period from July 1, 2018 to September 30, 2018 . The two-class method dictates that net income (loss) for a period be reduced by the amount of available cash that will be distributed with respect to that period and that any residual amount representing undistributed net income be allocated to common unitholders and other participating unitholders to the extent that each unit may share in net income as if all of the net income for the period had been distributed in accordance with the partnership agreement. Undistributed income is allocated to participating securities based on the distribution waterfall for available cash specified in the partnership agreement. Undistributed losses (including those resulting from distributions in excess of net income) are allocated to common units and other participating securities on a pro rata basis based on provisions of the partnership agreement. Distributions are treated as distributed earnings in the computation of earnings per common unit even though cash distributions are not necessarily derived from current or prior period earnings. The Class B units , which were mandatorily converted into our common units in accordance with the terms of our partnership agreement on August 2, 2017, were issued at a discount to the market price of the common units into which they were convertible. This discount, totaling $2,130 million , represented a beneficial conversion feature and was reflected as an increase in common and subordinated unitholders’ equity and a decrease in Class B unitholders’ equity to reflect the fair value of the Class B units at issuance on our Consolidated Statement of Partners’ Equity. The beneficial conversion feature was considered a dividend that was distributed ratably with respect to any Class B unit from its issuance date through its conversion date, which resulted in an increase in Class B unitholders’ equity and a decrease in common and subordinated unitholders’ equity. We amortized the beneficial conversion feature through the mandatory conversion date of August 2, 2017 using the effective yield method, with a weighted average effective yield of 888.7% per year and 966.1% per year for Cheniere Holdings’ previously held Class B units and Blackstone CQP Holdco ’s Class B units , respectively. The impact of the beneficial conversion feature was also included in earnings per unit for the three and nine months ended September 30, 2017 . The following table provides a reconciliation of net income and the allocation of net income to the common units, the subordinated units, the general partner units and IDRs for purposes of computing basic and diluted net income (loss) per unit (in millions, except per unit data). Limited Partner Units Total Common Units Class B Units Subordinated Units General Partner Units IDR Three Months Ended September 30, 2018 Net income $ 307 Declared distributions 297 202 — 79 5 11 Assumed allocation of undistributed net income (1) $ 10 7 — 3 — — Assumed allocation of net income $ 209 $ — $ 82 $ 5 $ 11 Weighted average units outstanding 348.6 — 135.4 Basic and diluted net income per unit (2) $ 0.60 $ 0.60 Three Months Ended September 30, 2017 Net income $ 23 Declared distributions 217 153 — 60 4 — Amortization of beneficial conversion feature of Class B units — (288 ) 974 (686 ) — — Assumed allocation of undistributed net loss $ (194 ) (137 ) — (53 ) (4 ) — Assumed allocation of net income $ (272 ) $ 974 $ (679 ) $ — $ — Weighted average units outstanding 247.2 50.6 135.4 Basic and diluted net loss per unit (2) $ (1.10 ) $ (5.02 ) Nine Months Ended September 30, 2018 Net income $ 923 Declared distributions 859 589 — 229 17 24 Assumed allocation of undistributed net income (1) $ 64 45 — 18 1 — Assumed allocation of net income $ 634 $ — $ 247 $ 18 $ 24 Weighted average units outstanding 348.6 — 135.4 Basic and diluted net income per unit $ 1.82 $ 1.82 Nine Months Ended September 30, 2017 Net income $ 116 Declared distributions 267 202 — 60 5 — Amortization of beneficial conversion feature of Class B units — (594 ) 2,004 (1,410 ) — — Assumed allocation of undistributed net loss $ (151 ) (107 ) — (41 ) (3 ) — Assumed allocation of net income $ (499 ) $ 2,004 $ (1,391 ) $ 2 $ — Weighted average units outstanding 121.2 113.4 135.4 Basic and diluted net loss per unit (2) $ (4.12 ) $ (10.28 ) (1) Under our partnership agreement, the IDR s participate in net income (loss) only to the extent of the amount of cash distributions actually declared, thereby excluding the IDR s from participating in undistributed net income (loss). (2) Earnings per unit in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

Customer Concentration

Customer Concentration	9 Months Ended
	Sep. 30, 2018
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 Third-Party Revenues Percentage of Accounts Receivable from Third Parties Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2018 2017 2018 2017 2018 2017 Customer A 24% 31% 27% 42% 28% 39% Customer B 21% 24% 22% 26% 26% 32% Customer C 21% 35% 23% 18% 22% 26% Customer D 24% —% 18% —% 19% —%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2018
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): Nine Months Ended September 30, 2018 2017 Cash paid during the period for interest, net of amounts capitalized $ 586 $ 459 The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $204 million and $247 million as of September 30, 2018 and 2017 , respectively.

Recent Accounting Standards

Recent Accounting Standards	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards	RECENT ACCOUNTING STANDARDS The following table provides a brief description of a recent accounting standard that had not been adopted by us as of September 30, 2018 : Standard Description Expected Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2016-02, Leases (Topic 842) , and subsequent amendments thereto 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 may be adopted using either a modified retrospective approach to apply the standard at the beginning of the earliest period presented in the financial statements or an optional transition approach to apply the standard at the date of adoption with no retrospective adjustments to prior periods. Certain additional practical expedients are also available. January 1, 2019 We continue to evaluate the effect of this standard on our Consolidated Financial Statements. This evaluation process includes reviewing all forms of leases, performing a completeness assessment over the lease population, analyzing the practical expedients and assessing opportunities to make certain changes to our lease accounting information technology system in order to determine the best implementation strategy. Preliminarily, we anticipate a material impact from the requirement to recognize all leases on our Consolidated 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. We anticipate electing the optional transition method to initially apply the standard at the January 1, 2019 adoption date. We expect to elect the package of practical expedients permitted under the transition guidance which, among other things, allows the carryforward of prior conclusions related to lease identification and classification. We also expect to elect the practical expedient to retain our existing accounting for land easements which were not previously accounted for as leases. We have not yet determined whether we will elect any other practical expedients upon transition. Additionally, the following table provides a brief description of recent accounting standards that were adopted by us during the reporting period: Standard Description Date of Adoption Effect on our Consolidated 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 adopted this guidance on January 1, 2018, using the full retrospective method. The adoption of this guidance represents a change in accounting principle that will provide financial statement readers with enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of this guidance did not impact our previously reported consolidated financial statements in any prior period nor did it result in a cumulative effect adjustment to retained earnings. See Note 11—Revenues from Contracts with Customers for additional disclosures. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 The adoption of this guidance did not have an impact on our Consolidated Financial Statements or related disclosures.

Supplemental Guarantor Informat

Supplemental Guarantor Information	9 Months Ended
	Sep. 30, 2018
Supplemental Guarantor Information [Abstract]
Supplemental Guarantor Information	SUPPLEMENTAL GUARANTOR INFORMATION Our CQP Senior Notes are jointly and severally guaranteed by each of our subsidiaries other than SPL (the “Guarantors”) and, subject to certain conditions governing its guarantee, Sabine Pass LP (collectively with SPL, the “Non-Guarantors”). These guarantees are full and unconditional, subject to certain customary release provisions including (1) the sale, exchange, disposition or transfer (by merger, consolidation or otherwise) of the capital stock or all or substantially all of the assets of the Guarantors, (2) upon the liquidation or dissolution of a Guarantor, (3) following the release of a Guarantor from its guarantee obligations and (4) upon the legal defeasance or satisfaction and discharge of obligations under the CQP Indenture . See Note 10—Debt in this quarterly report and Note 11—Debt of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, 2017 for additional information regarding the CQP Senior Notes . The following is condensed consolidating financial information for CQP (“Parent Issuer”), the Guarantors on a combined basis and the Non-Guarantors on a combined basis. We have accounted for investments in subsidiaries using the equity method. Condensed Consolidating Balance Sheet September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated ASSETS Current assets Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 799 9 649 — 1,457 Accounts and other receivables 1 1 222 — 224 Accounts receivable—affiliate 1 46 21 (46 ) 22 Advances to affiliate — 100 174 (85 ) 189 Inventory — 12 76 — 88 Other current assets 19 1 35 — 55 Other current assets—affiliate — — 21 (21 ) — Total current assets 820 169 1,198 (152 ) 2,035 Property, plant and equipment, net 79 2,136 13,091 (24 ) 15,282 Debt issuance costs, net 1 — 14 — 15 Non-current derivative assets 9 — 16 — 25 Investments in subsidiaries 2,449 347 — (2,796 ) — Other non-current assets, net — 27 152 — 179 Total assets $ 3,358 $ 2,679 $ 14,471 $ (2,972 ) $ 17,536 LIABILITIES AND PARTNERS’ EQUITY Current liabilities Accounts payable $ 1 $ 5 $ 7 $ — $ 13 Accrued liabilities 44 20 439 — 503 Due to affiliates — 132 52 (131 ) 53 Deferred revenue — 24 95 — 119 Deferred revenue—affiliate — 21 — (21 ) — Derivative liabilities — — 6 — 6 Total current liabilities 45 202 599 (152 ) 694 Long-term debt, net 2,565 — 13,494 — 16,059 Non-current derivative liabilities — — 2 — 2 Other non-current liabilities — 5 5 — 10 Other non-current liabilities—affiliate — 23 — — 23 Partners’ equity 748 2,449 371 (2,820 ) 748 Total liabilities and partners’ equity $ 3,358 $ 2,679 $ 14,471 $ (2,972 ) $ 17,536 Condensed Consolidating Balance Sheet December 31, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated ASSETS Current assets Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 1,033 12 544 — 1,589 Accounts and other receivables — 2 189 — 191 Accounts receivable—affiliate — 36 163 (36 ) 163 Advances to affiliate — 20 26 (10 ) 36 Inventory — 10 85 — 95 Other current assets 8 3 54 — 65 Other current assets—affiliate — — 21 (21 ) — Total current assets 1,041 83 1,082 (67 ) 2,139 Property, plant and equipment, net 80 2,164 12,920 (25 ) 15,139 Debt issuance costs, net 20 — 18 — 38 Non-current derivative assets 14 — 17 — 31 Investments in subsidiaries 2,076 (63 ) — (2,013 ) — Other non-current assets, net — 37 169 — 206 Total assets $ 3,231 $ 2,221 $ 14,206 $ (2,105 ) $ 17,553 LIABILITIES AND PARTNERS’ EQUITY Current liabilities Accounts payable $ — $ 4 $ 8 $ — $ 12 Accrued liabilities 23 8 606 — 637 Due to affiliates — 47 66 (45 ) 68 Deferred revenue — 27 84 — 111 Deferred revenue—affiliate — 22 — (21 ) 1 Other current liabilities—affiliate — 1 — (1 ) — Total current liabilities 23 109 764 (67 ) 829 Long-term debt, net 2,569 — 13,477 — 16,046 Non-current derivative liabilities — — 3 — 3 Other non-current liabilities — 11 — — 11 Other non-current liabilities—affiliate — 25 — — 25 Partners’ equity (deficit) 639 2,076 (38 ) (2,038 ) 639 Total liabilities and partners’ equity (deficit) $ 3,231 $ 2,221 $ 14,206 $ (2,105 ) $ 17,553 Condensed Consolidating Statement of Operations Three Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 1,249 $ — $ 1,249 LNG revenues—affiliate — — 205 — 205 Regasification revenues — 66 — — 66 Regasification revenues—affiliate — 64 — (64 ) — Other revenues — 9 — — 9 Other revenues—affiliate — 48 — (48 ) — Total revenues — 187 1,454 (112 ) 1,529 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — — 758 (2 ) 756 Cost of sales—affiliate — — 8 (8 ) — Operating and maintenance expense — 17 96 — 113 Operating and maintenance expense—affiliate — 39 107 (115 ) 31 Development expense — 1 — — 1 General and administrative expense 1 1 1 — 3 General and administrative expense—affiliate 3 6 12 (3 ) 18 Depreciation and amortization expense 1 19 88 (1 ) 107 Impairment expense and loss on disposal of assets — 8 — — 8 Total operating costs and expenses 5 91 1,070 (129 ) 1,037 Income (loss) from operations (5 ) 96 384 17 492 Other income (expense) Interest expense, net of capitalized interest (36 ) (1 ) (146 ) — (183 ) Loss on modification or extinguishment of debt (12 ) — — — (12 ) Derivative gain, net 2 — — — 2 Equity earnings of subsidiaries 354 243 — (597 ) — Other income (expense) 4 (1 ) 5 — 8 Total other income (expense) 312 241 (141 ) (597 ) (185 ) Net income $ 307 $ 337 $ 243 $ (580 ) $ 307 Condensed Consolidating Statement of Operations Three Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 723 $ — $ 723 LNG revenues—affiliate — — 111 — 111 Regasification revenues — 65 — — 65 Regasification revenues—affiliate — 48 — (48 ) — Other revenues — 3 — — 3 Other revenues—affiliate — 51 — (50 ) 1 Total revenues — 167 834 (98 ) 903 Operating costs and expenses Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below) — (1 ) 488 3 490 Cost of sales—affiliate — — 5 (5 ) — Operating and maintenance expense 1 7 65 — 73 Operating and maintenance expense—affiliate 6 33 82 (90 ) 31 Development expense — — 1 — 1 General and administrative expense 1 1 3 — 5 General and administrative expense—affiliate 3 6 12 (3 ) 18 Depreciation and amortization expense 1 17 69 — 87 Other — 1 — — 1 Total operating costs and expenses 12 64 725 (95 ) 706 Income (loss) from operations (12 ) 103 109 (3 ) 197 Other income (expense) Interest expense, net of capitalized interest (29 ) — (124 ) — (153 ) Loss on modification or extinguishment of debt (25 ) — — — (25 ) Derivative gain, net 1 — — — 1 Equity earnings (losses) of subsidiaries 88 (12 ) — (76 ) — Other income — — 3 — 3 Total other income (expense) 35 (12 ) (121 ) (76 ) (174 ) Net income (loss) $ 23 $ 91 $ (12 ) $ (79 ) $ 23 Condensed Consolidating Statement of Operations Nine Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 3,419 $ — $ 3,419 LNG revenues—affiliate — — 886 — 886 Regasification revenues — 196 — — 196 Regasification revenues—affiliate — 194 — (194 ) — Other revenues — 28 — — 28 Other revenues—affiliate — 183 — (183 ) — Total revenues — 601 4,305 (377 ) 4,529 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — 2 2,291 (2 ) 2,291 Cost of sales—affiliate — — 23 (23 ) — Operating and maintenance expense — 48 258 — 306 Operating and maintenance expense—affiliate — 113 317 (343 ) 87 Development expense — 1 1 — 2 General and administrative expense 3 2 4 — 9 General and administrative expense—affiliate 9 17 36 (9 ) 53 Depreciation and amortization expense 2 56 261 (1 ) 318 Impairment expense and loss on disposal of assets — 8 — — 8 Total operating costs and expenses 14 247 3,191 (378 ) 3,074 Income (loss) from operations (14 ) 354 1,114 1 1,455 Other income (expense) Interest expense, net of capitalized interest (104 ) (3 ) (445 ) — (552 ) Loss on modification or extinguishment of debt (12 ) — — — (12 ) Derivative gain, net 13 — — — 13 Equity earnings of subsidiaries 1,030 678 — (1,708 ) — Other income 10 — 9 — 19 Total other income (expense) 937 675 (436 ) (1,708 ) (532 ) Net income $ 923 $ 1,029 $ 678 $ (1,707 ) $ 923 Condensed Consolidating Statement of Operations Nine Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 1,718 $ — $ 1,718 LNG revenues—affiliate — — 864 — 864 Regasification revenues — 195 — — 195 Regasification revenues—affiliate — 128 — (128 ) — Other revenues — 7 — — 7 Other revenues—affiliate — 162 — (160 ) 2 Total revenues — 492 2,582 (288 ) 2,786 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — 1 1,576 3 1,580 Cost of sales—affiliate — — 15 (15 ) — Operating and maintenance expense 4 29 172 — 205 Operating and maintenance expense—affiliate 6 96 224 (256 ) 70 Development expense — — 2 — 2 General and administrative expense 3 2 5 — 10 General and administrative expense—affiliate 9 19 46 (11 ) 63 Depreciation and amortization expense 1 55 183 — 239 Other — 1 — — 1 Total operating costs and expenses 23 203 2,223 (279 ) 2,170 Income (loss) from operations (23 ) 289 359 (9 ) 616 Other income (expense) Interest expense, net of capitalized interest (81 ) — (356 ) — (437 ) Loss on modification or extinguishment of debt (25 ) — (42 ) — (67 ) Derivative loss, net — — (2 ) — (2 ) Equity earnings (losses) of subsidiaries 244 (36 ) — (208 ) — Other income 1 — 5 — 6 Total other income (expense) 139 (36 ) (395 ) (208 ) (500 ) Net income (loss) $ 116 $ 253 $ (36 ) $ (217 ) $ 116 Condensed Consolidating Statement of Cash Flows Nine Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash flows provided by operating activities $ 339 $ 408 $ 928 $ (411 ) $ 1,264 Cash flows from investing activities Property, plant and equipment, net — (24 ) (554 ) — (578 ) Investments in subsidiaries (202 ) (81 ) — 283 — Distributions received from affiliates, net 447 350 — (797 ) — Net cash provided by (used in) investing activities 245 245 (554 ) (514 ) (578 ) Cash flows from financing activities Proceeds from issuances of debt 1,100 — — — 1,100 Repayments of debt (1,090 ) — — — (1,090 ) Debt issuance and deferred financing costs (8 ) — — — (8 ) Debt extinguishment costs (6 ) — — — (6 ) Distributions to parent — (858 ) (350 ) 1,208 — Contributions from parent — 202 81 (283 ) — Distributions to owners (814 ) — — — (814 ) Net cash used in financing activities (818 ) (656 ) (269 ) 925 (818 ) Net increase (decrease) in cash, cash equivalents and restricted cash (234 ) (3 ) 105 — (132 ) Cash, cash equivalents and restricted cash—beginning of period 1,033 12 544 — 1,589 Cash, cash equivalents and restricted cash—end of period $ 799 $ 9 $ 649 $ — $ 1,457 Balances per Condensed Consolidating Balance Sheet: September 30, 2018 Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 799 9 649 — 1,457 Total cash, cash equivalents and restricted cash $ 799 $ 9 $ 649 $ — $ 1,457 Condensed Consolidating Statement of Cash Flows Nine Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash flows provided by (used in) operating activities $ (89 ) $ 293 $ 317 $ (8 ) $ 513 Cash flows from investing activities Property, plant and equipment, net — (16 ) (1,187 ) 8 (1,195 ) Investments in subsidiaries (216 ) (7 ) — 223 — Distributions received from affiliates, net 929 450 — (1,379 ) — Net cash provided by (used in) investing activities 713 427 (1,187 ) (1,148 ) (1,195 ) Cash flows from financing activities Proceeds from issuances of debt 1,500 — 2,314 — 3,814 Repayments of debt (1,470 ) — (703 ) — (2,173 ) Debt issuance and deferred financing costs (18 ) — (29 ) — (47 ) Distributions to parent — (929 ) (450 ) 1,379 — Contributions from parent — 216 7 (223 ) — Distributions to owners (74 ) — — — (74 ) Net cash provided by (used in) financing activities (62 ) (713 ) 1,139 1,156 1,520 Net increase in cash, cash equivalents and restricted cash 562 7 269 — 838 Cash, cash equivalents and restricted cash—beginning of period 234 13 358 — 605 Cash, cash equivalents and restricted cash—end of period $ 796 $ 20 $ 627 $ — $ 1,443

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Consolidated Financial Statements of Cheniere Partners 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 Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2017 . 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 did not have a material effect on our consolidated financial position, results of operations or cash flows.
Income Taxes, Policy	We are not subject to either federal or state income tax, as our partners are taxed individually on their allocable share of our taxable income.

Restricted Cash (Tables)

Restricted Cash (Tables)	9 Months Ended
	Sep. 30, 2018
Restricted Cash [Abstract]
Schedule of Restricted Cash	As of September 30, 2018 and December 31, 2017 , restricted cash consisted of the following (in millions): September 30, December 31, 2018 2017 Current restricted cash Liquefaction Project $ 649 $ 544 Cash held by us and our guarantor subsidiaries 808 1,045 Total current restricted cash $ 1,457 $ 1,589

Accounts and Other Receivables

Accounts and Other Receivables (Tables)	9 Months Ended
	Sep. 30, 2018
Receivables [Abstract]
Schedule of Accounts and Other Receivables	As of September 30, 2018 and December 31, 2017 , accounts and other receivables consisted of the following (in millions): September 30, December 31, 2018 2017 SPL trade receivable $ 213 $ 185 Other accounts receivable 11 6 Total accounts and other receivables $ 224 $ 191

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Schedule of Inventory	As of September 30, 2018 and December 31, 2017 , inventory consisted of the following (in millions): September 30, December 31, 2018 2017 Natural gas $ 9 $ 17 LNG 21 26 Materials and other 58 52 Total inventory $ 88 $ 95

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	As of September 30, 2018 and December 31, 2017 , property, plant and equipment, net consisted of the following (in millions): September 30, December 31, 2018 2017 LNG terminal costs LNG terminal and interconnecting pipeline facilities $ 12,706 $ 12,703 LNG terminal construction-in-process 3,757 3,310 Accumulated depreciation (1,187 ) (880 ) Total LNG terminal costs, net 15,276 15,133 Fixed assets Fixed assets 26 23 Accumulated depreciation (20 ) (17 ) Total fixed assets, net 6 6 Property, plant and equipment, net $ 15,282 $ 15,139

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosures [Line Items]
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 September 30, 2018 and December 31, 2017 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in millions). Fair Value Measurements as of September 30, 2018 December 31, 2017 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 CQP Interest Rate Derivatives asset $ — $ 28 $ — $ 28 $ — $ 21 $ — $ 21 Liquefaction Supply Derivatives asset (liability) (1 ) 1 19 19 2 10 43 55
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 September 30, 2018 : Net Fair Value Asset (in millions) Valuation Approach Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $19 Market approach incorporating present value techniques Basis Spread $(0.448) - $0.079
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 nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Balance, beginning of period $ 11 $ 40 $ 43 $ 79 Realized and mark-to-market gains (losses): Included in cost of sales 4 (8 ) (5 ) (43 ) Purchases and settlements: Purchases 4 (1 ) 8 1 Settlements 1 (2 ) (27 ) (8 ) Transfers out of Level 3 (1) (1 ) — — — Balance, end of period $ 19 $ 29 $ 19 $ 29 Change in unrealized gains relating to instruments still held at end of period $ 4 $ (8 ) $ (5 ) $ (43 ) (1) Transferred to Level 2 as a result of observable market for the underlying natural gas purchase agreements.
Derivative Net Presentation on Consolidated 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 Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets Offsetting Derivative Assets (Liabilities) As of September 30, 2018 CQP Interest Rate Derivatives $ 28 $ — $ 28 Liquefaction Supply Derivatives 31 (4 ) 27 Liquefaction Supply Derivatives (13 ) 5 (8 ) As of December 31, 2017 CQP Interest Rate Derivatives $ 21 $ — $ 21 Liquefaction Supply Derivatives 64 (6 ) 58 Liquefaction Supply Derivatives (3 ) — (3 )
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions	As of September 30, 2018 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received CQP Interest Rate Derivatives $225 million $1.3 billion March 22, 2016 February 29, 2020 1.19% One-month LIBOR
Fair Value of Derivative Instruments by Balance Sheet Location	The following table shows the fair value and location of the CQP Interest Rate Derivatives on our Consolidated Balance Sheets (in millions): September 30, December 31, Consolidated Balance Sheet Location 2018 2017 Other current assets $ 19 $ 7 Non-current derivative assets 9 14 Total derivative assets $ 28 $ 21
Derivative Instruments, Gain (Loss)	The following table shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Income during the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 CQP Interest Rate Derivatives gain $ 2 $ 1 $ 13 $ — SPL Interest Rate Derivatives loss — — — (2 )
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
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 Consolidated Balance Sheets (in millions): Fair Value Measurements as of (1) Consolidated Balance Sheet Location September 30, 2018 December 31, 2017 Other current assets $ 11 $ 41 Non-current derivative assets 16 17 Total derivative assets 27 58 Derivative liabilities (6 ) — Non-current derivative liabilities (2 ) (3 ) Total derivative liabilities (8 ) (3 ) Derivative asset, net $ 19 $ 55 (1) Does not include collateral calls of $2 million and $1 million as of September 30, 2018 and December 31, 2017 , respectively, for such contracts, which are included in other current assets in our Consolidated Balance Sheets.
Derivative Instruments, Gain (Loss)	The following table shows the changes in the fair value and settlements of our Liquefaction Supply Derivatives recorded in cost of sales on our Consolidated Statements of Income during the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Liquefaction Supply Derivatives gain (loss) (1) $ 10 $ (11 ) $ (42 ) $ (51 ) (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.

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	9 Months Ended
	Sep. 30, 2018
Other Assets, Noncurrent [Abstract]
Schedule of Other Non-Current Assets	As of September 30, 2018 and December 31, 2017 , other non-current assets, net consisted of the following (in millions): September 30, December 31, 2018 2017 Advances made under EPC and non-EPC contracts $ 15 $ 26 Advances made to municipalities for water system enhancements 90 93 Advances and other asset conveyances to third parties to support LNG terminals 29 30 Tax-related payments and receivables 17 25 Information technology service assets 20 24 Other 8 8 Total other non-current assets, net $ 179 $ 206

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2018
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of September 30, 2018 and December 31, 2017 , accrued liabilities consisted of the following (in millions): September 30, December 31, 2018 2017 Interest costs and related debt fees $ 186 $ 253 Accrued natural gas purchases 249 298 LNG terminal and related pipeline costs 59 86 Other accrued liabilities 9 — Total accrued liabilities $ 503 $ 637

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of September 30, 2018 and December 31, 2017 , our debt consisted of the following (in millions): September 30, December 31, 2018 2017 Long-term debt: SPL 5.625% Senior Secured Notes due 2021 (“2021 SPL Senior Notes”) $ 2,000 $ 2,000 6.25% Senior Secured Notes due 2022 (“2022 SPL Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 SPL Senior Notes”) 1,500 1,500 5.75% Senior Secured Notes due 2024 (“2024 SPL Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 SPL Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 SPL Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 SPL Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 SPL Senior Notes”) 1,350 1,350 5.00% Senior Secured Notes due 2037 (“2037 SPL Senior Notes”) 800 800 Cheniere Partners 5.250% Senior Notes due 2025 (“2025 CQP Senior Notes”) 1,500 1,500 5.625% Senior Notes due 2026 (“2026 CQP Senior Notes”) 1,100 — CQP Credit Facilities — 1,090 Unamortized premium, discount and debt issuance costs, net (191 ) (194 ) Total long-term debt, net 16,059 16,046 Current debt: $1.2 billion SPL Working Capital Facility (“SPL Working Capital Facility”) — — Total debt, net $ 16,059 $ 16,046
Schedule of Line of Credit Facilities	Below is a summary of our credit facilities outstanding as of September 30, 2018 (in millions): SPL Working Capital Facility CQP Credit Facilities Original facility size $ 1,200 $ 2,800 Less: Outstanding balance — — Commitments prepaid or terminated — 2,685 Letters of credit issued 494 — Available commitment $ 706 $ 115 Interest rate LIBOR plus 1.75% or base rate plus 0.75% LIBOR plus 2.25% or base rate plus 1.25% (1) Maturity date December 31, 2020, with various terms for underlying loans February 25, 2020 (1) There is a 0.50% step-up for both LIBOR and base rate loans beginning on February 25, 2019.
Schedule of Interest Expense	Total interest expense consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total interest cost $ 235 $ 227 $ 701 $ 662 Capitalized interest (52 ) (74 ) (149 ) (225 ) Total interest expense, net $ 183 $ 153 $ 552 $ 437
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): September 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes (1) $ 15,268 $ 16,098 $ 14,166 $ 15,485 2037 SPL Senior Notes (2) 791 831 790 871 Credit facilities (3) — — 1,090 1,090 (1) Includes 2021 SPL Senior Notes , 2022 SPL Senior Notes , 2023 SPL Senior Notes , 2024 SPL Senior Notes , 2025 SPL Senior Notes , 2026 SPL Senior Notes , 2027 SPL Senior Notes , 2028 SPL Senior Notes , 2025 CQP Senior Notes and 2026 CQP 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 our stock price and 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 SPL Working Capital Facility and CQP Credit Facilities . 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.

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2018
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 nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 LNG revenues $ 1,185 $ 717 $ 3,302 $ 1,695 LNG revenues—affiliate 205 111 886 864 Regasification revenues 66 65 196 195 Other revenues 9 3 28 7 Other revenues—affiliate — 1 — 2 Total revenues from customers 1,465 897 4,412 2,763 Gains from derivative instruments (1) 64 6 117 23 Total revenues $ 1,529 $ 903 $ 4,529 $ 2,786 (1) Includes the realized value associated with a portion of derivative instruments that settle through physical delivery.
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenues on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2018 Deferred revenues, beginning of period $ 111 Cash received but not yet recognized 119 Revenue recognized from prior period deferral (111 ) Deferred revenues, end of period $ 119
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 September 30, 2018 : Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 54.2 10.2 Regasification revenues 2.7 5.8 Total revenues $ 56.9 (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.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Consolidated Statements of Income for the three and nine months ended September 30, 2018 and 2017 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 205 $ 111 $ 886 $ 864 Other revenues—affiliate Terminal Marine Services Agreement — 1 — 2 Operating and maintenance expense—affiliate Services Agreements 31 25 87 64 Other agreements — 6 — 6 Total operating and maintenance expense—affiliate 31 31 87 70 General and administrative expense—affiliate Services Agreements 18 18 53 63

Net Income (Loss) per Common _2

Net Income (Loss) per Common Unit (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Schedule of Net Income (Loss) per Common Unit	The following table provides a reconciliation of net income and the allocation of net income to the common units, the subordinated units, the general partner units and IDRs for purposes of computing basic and diluted net income (loss) per unit (in millions, except per unit data). Limited Partner Units Total Common Units Class B Units Subordinated Units General Partner Units IDR Three Months Ended September 30, 2018 Net income $ 307 Declared distributions 297 202 — 79 5 11 Assumed allocation of undistributed net income (1) $ 10 7 — 3 — — Assumed allocation of net income $ 209 $ — $ 82 $ 5 $ 11 Weighted average units outstanding 348.6 — 135.4 Basic and diluted net income per unit (2) $ 0.60 $ 0.60 Three Months Ended September 30, 2017 Net income $ 23 Declared distributions 217 153 — 60 4 — Amortization of beneficial conversion feature of Class B units — (288 ) 974 (686 ) — — Assumed allocation of undistributed net loss $ (194 ) (137 ) — (53 ) (4 ) — Assumed allocation of net income $ (272 ) $ 974 $ (679 ) $ — $ — Weighted average units outstanding 247.2 50.6 135.4 Basic and diluted net loss per unit (2) $ (1.10 ) $ (5.02 ) Nine Months Ended September 30, 2018 Net income $ 923 Declared distributions 859 589 — 229 17 24 Assumed allocation of undistributed net income (1) $ 64 45 — 18 1 — Assumed allocation of net income $ 634 $ — $ 247 $ 18 $ 24 Weighted average units outstanding 348.6 — 135.4 Basic and diluted net income per unit $ 1.82 $ 1.82 Nine Months Ended September 30, 2017 Net income $ 116 Declared distributions 267 202 — 60 5 — Amortization of beneficial conversion feature of Class B units — (594 ) 2,004 (1,410 ) — — Assumed allocation of undistributed net loss $ (151 ) (107 ) — (41 ) (3 ) — Assumed allocation of net income $ (499 ) $ 2,004 $ (1,391 ) $ 2 $ — Weighted average units outstanding 121.2 113.4 135.4 Basic and diluted net loss per unit (2) $ (4.12 ) $ (10.28 ) (1) Under our partnership agreement, the IDR s participate in net income (loss) only to the extent of the amount of cash distributions actually declared, thereby excluding the IDR s from participating in undistributed net income (loss). (2) Earnings per unit in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

Customer Concentration (Tables)

Customer Concentration (Tables)	9 Months Ended
	Sep. 30, 2018
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 Third-Party Revenues Percentage of Accounts Receivable from Third Parties Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2018 2017 2018 2017 2018 2017 Customer A 24% 31% 27% 42% 28% 39% Customer B 21% 24% 22% 26% 26% 32% Customer C 21% 35% 23% 18% 22% 26% Customer D 24% —% 18% —% 19% —%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Nine Months Ended September 30, 2018 2017 Cash paid during the period for interest, net of amounts capitalized $ 586 $ 459

Recent Accounting Standards (Ta

Recent Accounting Standards (Tables)	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards, Not Yet Adopted	The following table provides a brief description of a recent accounting standard that had not been adopted by us as of September 30, 2018 : Standard Description Expected Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2016-02, Leases (Topic 842) , and subsequent amendments thereto 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 may be adopted using either a modified retrospective approach to apply the standard at the beginning of the earliest period presented in the financial statements or an optional transition approach to apply the standard at the date of adoption with no retrospective adjustments to prior periods. Certain additional practical expedients are also available. January 1, 2019 We continue to evaluate the effect of this standard on our Consolidated Financial Statements. This evaluation process includes reviewing all forms of leases, performing a completeness assessment over the lease population, analyzing the practical expedients and assessing opportunities to make certain changes to our lease accounting information technology system in order to determine the best implementation strategy. Preliminarily, we anticipate a material impact from the requirement to recognize all leases on our Consolidated 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. We anticipate electing the optional transition method to initially apply the standard at the January 1, 2019 adoption date. We expect to elect the package of practical expedients permitted under the transition guidance which, among other things, allows the carryforward of prior conclusions related to lease identification and classification. We also expect to elect the practical expedient to retain our existing accounting for land easements which were not previously accounted for as leases. We have not yet determined whether we will elect any other practical expedients upon transition.
Recent Accounting Standards, Adopted	Additionally, the following table provides a brief description of recent accounting standards that were adopted by us during the reporting period: Standard Description Date of Adoption Effect on our Consolidated 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 adopted this guidance on January 1, 2018, using the full retrospective method. The adoption of this guidance represents a change in accounting principle that will provide financial statement readers with enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of this guidance did not impact our previously reported consolidated financial statements in any prior period nor did it result in a cumulative effect adjustment to retained earnings. See Note 11—Revenues from Contracts with Customers for additional disclosures. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 The adoption of this guidance did not have an impact on our Consolidated Financial Statements or related disclosures.

Supplemental Guarantor Inform_2

Supplemental Guarantor Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Guarantor Information [Abstract]
Condensed Consolidating Balance Sheet	Condensed Consolidating Balance Sheet September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated ASSETS Current assets Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 799 9 649 — 1,457 Accounts and other receivables 1 1 222 — 224 Accounts receivable—affiliate 1 46 21 (46 ) 22 Advances to affiliate — 100 174 (85 ) 189 Inventory — 12 76 — 88 Other current assets 19 1 35 — 55 Other current assets—affiliate — — 21 (21 ) — Total current assets 820 169 1,198 (152 ) 2,035 Property, plant and equipment, net 79 2,136 13,091 (24 ) 15,282 Debt issuance costs, net 1 — 14 — 15 Non-current derivative assets 9 — 16 — 25 Investments in subsidiaries 2,449 347 — (2,796 ) — Other non-current assets, net — 27 152 — 179 Total assets $ 3,358 $ 2,679 $ 14,471 $ (2,972 ) $ 17,536 LIABILITIES AND PARTNERS’ EQUITY Current liabilities Accounts payable $ 1 $ 5 $ 7 $ — $ 13 Accrued liabilities 44 20 439 — 503 Due to affiliates — 132 52 (131 ) 53 Deferred revenue — 24 95 — 119 Deferred revenue—affiliate — 21 — (21 ) — Derivative liabilities — — 6 — 6 Total current liabilities 45 202 599 (152 ) 694 Long-term debt, net 2,565 — 13,494 — 16,059 Non-current derivative liabilities — — 2 — 2 Other non-current liabilities — 5 5 — 10 Other non-current liabilities—affiliate — 23 — — 23 Partners’ equity 748 2,449 371 (2,820 ) 748 Total liabilities and partners’ equity $ 3,358 $ 2,679 $ 14,471 $ (2,972 ) $ 17,536 Condensed Consolidating Balance Sheet December 31, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated ASSETS Current assets Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 1,033 12 544 — 1,589 Accounts and other receivables — 2 189 — 191 Accounts receivable—affiliate — 36 163 (36 ) 163 Advances to affiliate — 20 26 (10 ) 36 Inventory — 10 85 — 95 Other current assets 8 3 54 — 65 Other current assets—affiliate — — 21 (21 ) — Total current assets 1,041 83 1,082 (67 ) 2,139 Property, plant and equipment, net 80 2,164 12,920 (25 ) 15,139 Debt issuance costs, net 20 — 18 — 38 Non-current derivative assets 14 — 17 — 31 Investments in subsidiaries 2,076 (63 ) — (2,013 ) — Other non-current assets, net — 37 169 — 206 Total assets $ 3,231 $ 2,221 $ 14,206 $ (2,105 ) $ 17,553 LIABILITIES AND PARTNERS’ EQUITY Current liabilities Accounts payable $ — $ 4 $ 8 $ — $ 12 Accrued liabilities 23 8 606 — 637 Due to affiliates — 47 66 (45 ) 68 Deferred revenue — 27 84 — 111 Deferred revenue—affiliate — 22 — (21 ) 1 Other current liabilities—affiliate — 1 — (1 ) — Total current liabilities 23 109 764 (67 ) 829 Long-term debt, net 2,569 — 13,477 — 16,046 Non-current derivative liabilities — — 3 — 3 Other non-current liabilities — 11 — — 11 Other non-current liabilities—affiliate — 25 — — 25 Partners’ equity (deficit) 639 2,076 (38 ) (2,038 ) 639 Total liabilities and partners’ equity (deficit) $ 3,231 $ 2,221 $ 14,206 $ (2,105 ) $ 17,553
Condensed Consolidating Statements of Operations	Condensed Consolidating Statement of Operations Three Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 1,249 $ — $ 1,249 LNG revenues—affiliate — — 205 — 205 Regasification revenues — 66 — — 66 Regasification revenues—affiliate — 64 — (64 ) — Other revenues — 9 — — 9 Other revenues—affiliate — 48 — (48 ) — Total revenues — 187 1,454 (112 ) 1,529 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — — 758 (2 ) 756 Cost of sales—affiliate — — 8 (8 ) — Operating and maintenance expense — 17 96 — 113 Operating and maintenance expense—affiliate — 39 107 (115 ) 31 Development expense — 1 — — 1 General and administrative expense 1 1 1 — 3 General and administrative expense—affiliate 3 6 12 (3 ) 18 Depreciation and amortization expense 1 19 88 (1 ) 107 Impairment expense and loss on disposal of assets — 8 — — 8 Total operating costs and expenses 5 91 1,070 (129 ) 1,037 Income (loss) from operations (5 ) 96 384 17 492 Other income (expense) Interest expense, net of capitalized interest (36 ) (1 ) (146 ) — (183 ) Loss on modification or extinguishment of debt (12 ) — — — (12 ) Derivative gain, net 2 — — — 2 Equity earnings of subsidiaries 354 243 — (597 ) — Other income (expense) 4 (1 ) 5 — 8 Total other income (expense) 312 241 (141 ) (597 ) (185 ) Net income $ 307 $ 337 $ 243 $ (580 ) $ 307 Condensed Consolidating Statement of Operations Three Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 723 $ — $ 723 LNG revenues—affiliate — — 111 — 111 Regasification revenues — 65 — — 65 Regasification revenues—affiliate — 48 — (48 ) — Other revenues — 3 — — 3 Other revenues—affiliate — 51 — (50 ) 1 Total revenues — 167 834 (98 ) 903 Operating costs and expenses Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below) — (1 ) 488 3 490 Cost of sales—affiliate — — 5 (5 ) — Operating and maintenance expense 1 7 65 — 73 Operating and maintenance expense—affiliate 6 33 82 (90 ) 31 Development expense — — 1 — 1 General and administrative expense 1 1 3 — 5 General and administrative expense—affiliate 3 6 12 (3 ) 18 Depreciation and amortization expense 1 17 69 — 87 Other — 1 — — 1 Total operating costs and expenses 12 64 725 (95 ) 706 Income (loss) from operations (12 ) 103 109 (3 ) 197 Other income (expense) Interest expense, net of capitalized interest (29 ) — (124 ) — (153 ) Loss on modification or extinguishment of debt (25 ) — — — (25 ) Derivative gain, net 1 — — — 1 Equity earnings (losses) of subsidiaries 88 (12 ) — (76 ) — Other income — — 3 — 3 Total other income (expense) 35 (12 ) (121 ) (76 ) (174 ) Net income (loss) $ 23 $ 91 $ (12 ) $ (79 ) $ 23 Condensed Consolidating Statement of Operations Nine Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 3,419 $ — $ 3,419 LNG revenues—affiliate — — 886 — 886 Regasification revenues — 196 — — 196 Regasification revenues—affiliate — 194 — (194 ) — Other revenues — 28 — — 28 Other revenues—affiliate — 183 — (183 ) — Total revenues — 601 4,305 (377 ) 4,529 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — 2 2,291 (2 ) 2,291 Cost of sales—affiliate — — 23 (23 ) — Operating and maintenance expense — 48 258 — 306 Operating and maintenance expense—affiliate — 113 317 (343 ) 87 Development expense — 1 1 — 2 General and administrative expense 3 2 4 — 9 General and administrative expense—affiliate 9 17 36 (9 ) 53 Depreciation and amortization expense 2 56 261 (1 ) 318 Impairment expense and loss on disposal of assets — 8 — — 8 Total operating costs and expenses 14 247 3,191 (378 ) 3,074 Income (loss) from operations (14 ) 354 1,114 1 1,455 Other income (expense) Interest expense, net of capitalized interest (104 ) (3 ) (445 ) — (552 ) Loss on modification or extinguishment of debt (12 ) — — — (12 ) Derivative gain, net 13 — — — 13 Equity earnings of subsidiaries 1,030 678 — (1,708 ) — Other income 10 — 9 — 19 Total other income (expense) 937 675 (436 ) (1,708 ) (532 ) Net income $ 923 $ 1,029 $ 678 $ (1,707 ) $ 923 Condensed Consolidating Statement of Operations Nine Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Revenues LNG revenues $ — $ — $ 1,718 $ — $ 1,718 LNG revenues—affiliate — — 864 — 864 Regasification revenues — 195 — — 195 Regasification revenues—affiliate — 128 — (128 ) — Other revenues — 7 — — 7 Other revenues—affiliate — 162 — (160 ) 2 Total revenues — 492 2,582 (288 ) 2,786 Operating costs and expenses Cost of sales (excluding depreciation and amortization expense shown separately below) — 1 1,576 3 1,580 Cost of sales—affiliate — — 15 (15 ) — Operating and maintenance expense 4 29 172 — 205 Operating and maintenance expense—affiliate 6 96 224 (256 ) 70 Development expense — — 2 — 2 General and administrative expense 3 2 5 — 10 General and administrative expense—affiliate 9 19 46 (11 ) 63 Depreciation and amortization expense 1 55 183 — 239 Other — 1 — — 1 Total operating costs and expenses 23 203 2,223 (279 ) 2,170 Income (loss) from operations (23 ) 289 359 (9 ) 616 Other income (expense) Interest expense, net of capitalized interest (81 ) — (356 ) — (437 ) Loss on modification or extinguishment of debt (25 ) — (42 ) — (67 ) Derivative loss, net — — (2 ) — (2 ) Equity earnings (losses) of subsidiaries 244 (36 ) — (208 ) — Other income 1 — 5 — 6 Total other income (expense) 139 (36 ) (395 ) (208 ) (500 ) Net income (loss) $ 116 $ 253 $ (36 ) $ (217 ) $ 116
Condensed Consolidating Statements of Cash Flows	Condensed Consolidating Statement of Cash Flows Nine Months Ended September 30, 2018 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash flows provided by operating activities $ 339 $ 408 $ 928 $ (411 ) $ 1,264 Cash flows from investing activities Property, plant and equipment, net — (24 ) (554 ) — (578 ) Investments in subsidiaries (202 ) (81 ) — 283 — Distributions received from affiliates, net 447 350 — (797 ) — Net cash provided by (used in) investing activities 245 245 (554 ) (514 ) (578 ) Cash flows from financing activities Proceeds from issuances of debt 1,100 — — — 1,100 Repayments of debt (1,090 ) — — — (1,090 ) Debt issuance and deferred financing costs (8 ) — — — (8 ) Debt extinguishment costs (6 ) — — — (6 ) Distributions to parent — (858 ) (350 ) 1,208 — Contributions from parent — 202 81 (283 ) — Distributions to owners (814 ) — — — (814 ) Net cash used in financing activities (818 ) (656 ) (269 ) 925 (818 ) Net increase (decrease) in cash, cash equivalents and restricted cash (234 ) (3 ) 105 — (132 ) Cash, cash equivalents and restricted cash—beginning of period 1,033 12 544 — 1,589 Cash, cash equivalents and restricted cash—end of period $ 799 $ 9 $ 649 $ — $ 1,457 Balances per Condensed Consolidating Balance Sheet: September 30, 2018 Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash and cash equivalents $ — $ — $ — $ — $ — Restricted cash 799 9 649 — 1,457 Total cash, cash equivalents and restricted cash $ 799 $ 9 $ 649 $ — $ 1,457 Condensed Consolidating Statement of Cash Flows Nine Months Ended September 30, 2017 (in millions) Parent Issuer Guarantors Non-Guarantors Eliminations Consolidated Cash flows provided by (used in) operating activities $ (89 ) $ 293 $ 317 $ (8 ) $ 513 Cash flows from investing activities Property, plant and equipment, net — (16 ) (1,187 ) 8 (1,195 ) Investments in subsidiaries (216 ) (7 ) — 223 — Distributions received from affiliates, net 929 450 — (1,379 ) — Net cash provided by (used in) investing activities 713 427 (1,187 ) (1,148 ) (1,195 ) Cash flows from financing activities Proceeds from issuances of debt 1,500 — 2,314 — 3,814 Repayments of debt (1,470 ) — (703 ) — (2,173 ) Debt issuance and deferred financing costs (18 ) — (29 ) — (47 ) Distributions to parent — (929 ) (450 ) 1,379 — Contributions from parent — 216 7 (223 ) — Distributions to owners (74 ) — — — (74 ) Net cash provided by (used in) financing activities (62 ) (713 ) 1,139 1,156 1,520 Net increase in cash, cash equivalents and restricted cash 562 7 269 — 838 Cash, cash equivalents and restricted cash—beginning of period 234 13 358 — 605 Cash, cash equivalents and restricted cash—end of period $ 796 $ 20 $ 627 $ — $ 1,443

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details)	9 Months Ended
	Sep. 30, 2018mitrains
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains | trains	6
CTPL [Member]
Nature of Operations and Basis of Presentation [Line Items]
Length Of Natural Gas Pipeline | mi	94

Unitholders' Equity (Details)

Unitholders' Equity (Details)	9 Months Ended
	Sep. 30, 2018$ / shares
Maximum [Member]
Other Ownership Interests [Line Items]
Number of days after quarter end distribution is paid	45 days
Common Units [Member]
Other Ownership Interests [Line Items]
Distributions Per Limited Partnership Unit Outstanding, Basic	$ 0.425
General Partner [Member] | Minimum [Member]
Other Ownership Interests [Line Items]
Distributions entitled by General Partner, Percentage	2.00%
Incentive Distribution, Quarterly Distribution Additional Target Percentage	15.00%
General Partner [Member] | Maximum [Member]
Other Ownership Interests [Line Items]
Incentive Distribution, Quarterly Distribution Additional Target Percentage	50.00%
Cheniere [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	48.60%
Blackstone [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	40.30%
Public [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	9.10%

Restricted Cash (Details)

Restricted Cash (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 1,457	$ 1,589
Liquefaction Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	649	544
Cash held by us and our guarantor subsidiaries [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 808	$ 1,045

Accounts and Other Receivable_2

Accounts and Other Receivables (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Receivables [Abstract]
SPL trade receivable	$ 213	$ 185
Other accounts receivable	11	6
Total accounts and other receivables	$ 224	$ 191

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Inventory [Line Items]
Inventory	$ 88	$ 95
Natural gas [Member]
Inventory [Line Items]
Inventory	9	17
LNG [Member]
Inventory [Line Items]
Inventory	21	26
Materials and other [Member]
Inventory [Line Items]
Inventory	$ 58	$ 52

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 15,282	$ 15,139
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(1,187)	(880)
Property, plant and equipment, net	15,276	15,133
LNG terminal and interconnecting pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	12,706	12,703
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	3,757	3,310
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	26	23
Accumulated depreciation	(20)	(17)
Property, plant and equipment, net	$ 6	$ 6

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Property, Plant and Equipment [Abstract]
Depreciation	$ 104	$ 85	$ 310	$ 233
Offsets to LNG terminal costs	$ 0	$ 79	$ 0	$ 242

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) $ in Millions	1 Months Ended			9 Months Ended
	Oct. 31, 2018USD ($)	Sep. 30, 2018USD ($)tbtu	Mar. 31, 2017USD ($)	Sep. 30, 2018tbtu	Dec. 31, 2017tbtu
CQP Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease		$ 1,200
CQP Interest Rate Derivatives [Member] | Subsequent Event [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Gain (Loss), Net	$ 28
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract				6 years
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount | tbtu		2,206		2,206	1,520
SPL [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Energy Units Secured Through Natural Gas Supply Contracts | tbtu		2,755		2,755	2,214
SPL [Member] | SPL Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease			$ 1,600
SPL [Member] | SPL Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Gain (Loss), Net			$ (7)

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
CQP Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 28	$ 21
CQP 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
CQP 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	28	21
CQP 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	19	55
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	(1)	2
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	1	10
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	$ 19	$ 43

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member]	9 Months Ended
	Sep. 30, 2018USD ($)
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset	$ 19,000,000
Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Input Range	(0.448)
Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Input Range	$ 0.079

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ 11	$ 40	$ 43	$ 79
Realized and mark-to-market gains (losses):
Included in cost of sales		4	(8)	(5)	(43)
Purchases and settlements:
Purchases		4	(1)	8	1
Settlements		1	(2)	(27)	(8)
Transfers out of Level 3	[1]	(1)	0	0	0
Balance, end of period		19	29	19	29
Change in unrealized gains relating to instruments still held at end of period		$ 4	$ (8)	$ (5)	$ (43)
[1]	Transferred to Level 2 as a result of observable market for the underlying natural gas purchase agreements.

Derivative Instruments - Sche_2

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - CQP Interest Rate Derivatives [Member] $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Derivative [Line Items]
Notional Amount	$ 225
Effective Date	Mar. 22, 2016
Maturity Date	Feb. 29, 2020
Weighted Average Fixed Interest Rate Paid	1.19%
Variable Interest Rate Received	One-month LIBOR
Maximum [Member]
Derivative [Line Items]
Notional Amount	$ 1,300

Derivative Instruments - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Non-current derivative assets		$ 25	$ 31
Derivative liabilities		(6)	0
Non-current derivative liabilities		(2)	(3)
CQP Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		28	21
CQP Interest Rate Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		19	7
CQP Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		9	14
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	27	58
Total derivative liabilities	[1]	(8)	(3)
Derivative asset, net	[1]	19	55
Derivative, collateral call		2	1
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	11	41
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	[1]	16	17
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	(6)	0
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	[1]	$ (2)	$ (3)
[1]	Does not include collateral calls of $2 million and $1 million as of September 30, 2018 and December 31, 2017, respectively, for such contracts, which are included in other current assets in our Consolidated Balance Sheets.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
CQP Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ 2	$ 1	$ 13	$ 0
SPL Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		0	0	0	(2)
Liquefaction Supply Derivatives [Member] | Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 10	$ (11)	$ (42)	$ (51)
[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 - Balanc

Derivative Instruments - Balance Sheet Presentation Table (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
CQP Interest Rate Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 28	$ 21
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Derivative Assets (Liabilities), at Fair Value, Net	28	21
Liquefaction Supply Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	31	64
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheet	(4)	(6)
Derivative Assets (Liabilities), at Fair Value, Net	27	58
Liquefaction Supply Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(13)	(3)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheet	5	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (8)	$ (3)

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Other Assets, Noncurrent [Abstract]
Advances made under EPC and non-EPC contracts	$ 15	$ 26
Advances made to municipalities for water system enhancements	90	93
Advances and other asset conveyances to third parties to support LNG terminals	29	30
Tax-related payments and receivables	17	25
Information technology service assets	20	24
Other	8	8
Other non-current assets, net	$ 179	$ 206

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 186	$ 253
Accrued natural gas purchases	249	298
LNG terminal and related pipeline costs	59	86
Other accrued liabilities	9	0
Total accrued liabilities	$ 503	$ 637

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Unamortized premium, discount and debt issuance costs, net	$ (191,000,000)	$ (194,000,000)
Long-term Debt, Net	16,059,000,000	16,046,000,000
Current Debt, Working Capital Facility	0	0
Total Debt, Net	16,059,000,000	16,046,000,000
2021 SPL 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 SPL 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 SPL 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 SPL 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 SPL 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 SPL 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 SPL 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 SPL 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 SPL 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%
2025 CQP 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	5.25%
2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,100,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.625%
CQP Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 0	1,090,000,000
SPL 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 - Debt Issuances and Redem

Debt - Debt Issuances and Redemptions - CQP 2026 Senior Notes (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Debt Instrument [Line Items]
Loss on modification or extinguishment of debt		$ 12	$ 25	$ 12	$ 67
2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate principal amount	$ 1,100	1,100		1,100
Proceeds from Debt, Net of Issuance Costs	$ 1,100
Loss on modification or extinguishment of debt		$ 12		$ 12
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%		5.625%
Debt Instrument, Redemption Price, Percentage				100.00%
Debt Instrument, Redemption Price, Percentage Price For Amount Which May Be Redeemed With Cash Proceeds From Certain Equity Offerings				105.625%
Debt Instrument Registration Period				360 days
2026 CQP Senior Notes [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Amount, Percentage of Principal Amount Which May Be Redeemed With Cash Proceeds From Certain Equity Offerings				35.00%
CQP Credit Facilities - Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Available commitment	$ 115	$ 115		$ 115
CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Secured Debt Condition, Secured Indebtedness and Attributable Indebtedness Threshold, Monetary Amount	$ 1,500	$ 1,500		$ 1,500
Debt Instrument, Secured Debt Condition, Secured Indebtedness and Attributable Indebtedness Threshold, Percentage of Net Tangible Assets				10.00%

Debt - Credit Facilities Table

Debt - Credit Facilities Table (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018	Dec. 31, 2017
Line of Credit Facility [Line Items]
Outstanding balance, current		$ 0	$ 0
SPL Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size		1,200
Outstanding balance, current		0	0
Commitments prepaid or terminated		0
Letters of credit issued		494
Available commitment		$ 706
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
SPL 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%
SPL Working Capital Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.75%
CQP Credit Facilities [Member]
Line of Credit Facility [Line Items]
Original facility size		$ 2,800
Outstanding balance		0	$ 1,090
Commitments prepaid or terminated		2,685
Letters of credit issued		0
Available commitment		$ 115
Debt Instrument, Description of Variable Rate Basis	[1]	LIBOR or base rate
Debt Instrument, Maturity Date, Description		February 25, 2020
CQP Credit Facilities [Member] | February 25, 2019 [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Interest Rate, Increase		0.50%
CQP Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	[1]	2.25%
CQP Credit Facilities [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	[1]	1.25%
[1]	There is a 0.50% step-up for both LIBOR and base rate loans beginning on February 25, 2019.

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Debt Disclosure [Abstract]
Total interest cost	$ 235	$ 227	$ 701	$ 662
Capitalized interest	(52)	(74)	(149)	(225)
Total interest expense, net	$ 183	$ 153	$ 552	$ 437

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt		$ 16,059	$ 16,046
Senior notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[1]	15,268	14,166
Senior notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	16,098	15,485
2037 SPL Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[2]	791	790
2037 SPL Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	831	871
Credit facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[3]	0	1,090
Credit facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Credit Facilities, Estimated Fair Value	[3]	$ 0	$ 1,090
[1]	Includes 2021 SPL Senior Notes, 2022 SPL Senior Notes, 2023 SPL Senior Notes, 2024 SPL Senior Notes, 2025 SPL Senior Notes, 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes, 2025 CQP Senior Notes and 2026 CQP 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 our stock price and 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 SPL Working Capital Facility and CQP Credit Facilities. 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.

Revenues from Contracts with _3

Revenues from Contracts with Customers (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)bcf / ditem	Sep. 30, 2017USD ($)
Disaggregation of Revenue [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
Regasification Capacity | bcf / d			4
Operating and maintenance expense | $	$ 113	$ 73	$ 306	$ 205
TUA Customers [Member]
Disaggregation of Revenue [Line Items]
Regasification Capacity | bcf / d			2
Number Of Fixed Price Contracts | item			2
TUA Customer 1 [Member]
Disaggregation of Revenue [Line Items]
Regasification Capacity | bcf / d			1
Revenue, Performance Obligation, Fixed Consideration | $			$ 125
Long-term Purchase Commitment, Period			20 years
TUA Customer 2 [Member]
Disaggregation of Revenue [Line Items]
Regasification Capacity | bcf / d			1
Revenue, Performance Obligation, Fixed Consideration | $			$ 125
Long-term Purchase Commitment, Period			20 years
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	55.00%		55.00%
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	100.00%		100.00%
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	3.00%		3.00%
Partial TUA Regasification Capacity [Member]
Disaggregation of Revenue [Line Items]
Operating and maintenance expense | $	$ 7.5	$ 7.5	$ 23	$ 15

Revenues from Contracts with _4

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		$ 1,465	$ 897	$ 4,412	$ 2,763
Total revenues		1,529	903	4,529	2,786
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		1,185	717	3,302	1,695
Total revenues		1,249	723	3,419	1,718
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		205	111	886	864
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		66	65	196	195
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		9	3	28	7
Other—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenue earned from contracts with customers		0	1	0	2
Derivative Instruments [Member]
Disaggregation of Revenue [Line Items]
Total revenues	[1]	$ 64	$ 6	$ 117	$ 23
[1]	Includes the realized value associated with a portion of derivative instruments that settle through physical delivery.

Revenues from Contracts with _5

Revenues from Contracts with Customers - Schedule of Deferred Revenue Reconciliation (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenues, beginning of period	$ 111
Cash received but not yet recognized	119
Revenue recognized from prior period deferral	(111)
Deferred revenues, end of period	$ 119

Revenues from Contracts with _6

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) $ in Billions	Sep. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price	$ 56.9
LNG [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price	$ 54.2
Weighted Average Recognition Timing	10 years 73 days	[1]
Regasification [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price	$ 2.7
Weighted Average Recognition Timing	5 years 299 days	[1]
[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.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	$ 31	$ 31	$ 87	$ 70
General and administrative expense—affiliate	18	18	53	63
Cheniere Marketing SPA and Cheniere Marketing Master SPA [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	205	111	886	864
Terminal Marine Services Agreement [Member]
Related Party Transaction [Line Items]
Other revenues—affiliate	0	1	0	2
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	31	25	87	64
General and administrative expense—affiliate	18	18	53	63
Other Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	$ 0	$ 6	$ 0	$ 6

Related Party Transactions - LN

Related Party Transactions - LNG Terminal Capacity Agreements (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)bcf / d$ / MMBTU	Sep. 30, 2017USD ($)
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d			4
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
Terminal Use Agreement [Member] | SPLNG [Member] | SPL [Member]
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d			2
Related Party Transaction, Committed Annual Fee | $			$ 250,000,000
Amended and Restated Variable Capacity Rights Agreement [Member] | Cheniere Marketing [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Proceeds (Payments) of Gross Margin Earned, Percentage			80.00%
LNG revenues—affiliate | $	$ 0	$ 0	$ 0	$ 0
LNG Sale and Purchase Agreement [Member] | Cheniere Marketing [Member] | SPL [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price Per MMBtu | $ / MMBTU			3

Related Party Transactions - Se

Related Party Transactions - Service Agreements (Details) - USD ($)	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Advances to Affiliate Current	$ 189,000,000	$ 36,000,000
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to Affiliate Current	189,000,000	$ 36,000,000
Cheniere Partners Services Agreement [Member] | Cheniere Terminals [Member]
Related Party Transaction [Line Items]
Quarterly non-accountable overhead reimbursement charge	$ 3,000,000
Operation and Maintenance Agreement [Member] | Cheniere Investments [Member] | SPL [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
Operation and Maintenance Agreement [Member] | Cheniere Investments [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	$ 130,000
Related Party Transaction, Bonus Percentage of Salary Entitled Upon Meeting Certain Criteria	50.00%
Management Services Agreement [Member] | Cheniere Terminals [Member] | SPL [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
Management Services Agreement [Member] | Cheniere Terminals [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	$ 520,000

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Due to affiliates	$ 53,000,000		$ 53,000,000		$ 68,000,000
Other non-current liabilities—affiliate	23,000,000		$ 23,000,000		25,000,000
Cooperative Endeavor Agreements [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Tax Initiative Agreement Term			10 years
Aggregate commitment under the Agreement	25,000,000		$ 25,000,000
Cooperative Endeavor Agreements [Member] | Cheniere Marketing [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Due to affiliates	2,000,000		2,000,000
Other non-current liabilities—affiliate	23,000,000		23,000,000		$ 25,000,000
Terminal Marine Services Agreement [Member] | Wholly owned subsidiary of Cheniere [Member] | Tug Services [Member]
Related Party Transaction [Line Items]
General Partner Distributions			4,000,000
LNG Terminal Export Agreement [Member] | Cheniere Marketing [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 0	$ 0	0	$ 0
Tax Sharing Agreement [Member] | Cheniere [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			0
Tax Sharing Agreement [Member] | Cheniere [Member] | SPL [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			0
Tax Sharing Agreement [Member] | Cheniere [Member] | CTPL [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			$ 0

Net Income (Loss) per Common _3

Net Income (Loss) per Common Unit - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Oct. 26, 2018	Sep. 30, 2018
Class B Units [Member]
Distribution Made to Limited Partner [Line Items]
Discount upon issuance of Class B units representing beneficial conversion feature		$ 2,130
Cheniere Holdings [Member] | Class B Units [Member] | Effective Yield Method [Member]
Distribution Made to Limited Partner [Line Items]
Amortization of Beneficial Conversion Feature of Class B Units		888.70%
Blackstone [Member] | Class B Units [Member] | Effective Yield Method [Member]
Distribution Made to Limited Partner [Line Items]
Amortization of Beneficial Conversion Feature of Class B Units		966.10%
Subsequent Event [Member] | Common Units [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.58
Subsequent Event [Member] | Subordinated Units [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.58

Net Income (Loss) per Common _4

Net Income (Loss) per Common Unit - Schedule of Net Income (Loss) per Unit and Allocation of Distribution (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017		Sep. 30, 2018		Sep. 30, 2017
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income	$ 307		$ 23		$ 923		$ 116
Declared distributions	297		217		859		267
Amortization of beneficial conversion feature of Class B units			0				0
Assumed allocation of undistributed net income	$ 10	[1]	$ (194)		$ 64	[1]	$ (151)
Weighted average units outstanding	348.6		247.2		348.6		121.2
Basic and diluted net income (loss) per unit	$ 0.60		$ (1.10)		$ 1.82		$ (4.12)
Common Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income					$ 651
Declared distributions	$ 202		$ 153		589		$ 202
Amortization of beneficial conversion feature of Class B units			(288)				(594)
Assumed allocation of undistributed net income	7	[1]	(137)		45	[1]	(107)
Assumed allocation of net income	$ 209		$ (272)		$ 634		$ (499)
Weighted average units outstanding	348.6		247.2		348.6		121.2
Basic and diluted net income (loss) per unit	$ 0.60	[2]	$ (1.10)	[2]	$ 1.82		$ (4.12)	[2]
Class B Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Declared distributions	$ 0		$ 0		$ 0		$ 0
Amortization of beneficial conversion feature of Class B units			974				2,004
Assumed allocation of undistributed net income	0	[1]	0		0	[1]	0
Assumed allocation of net income	$ 0		$ 974		$ 0		$ 2,004
Weighted average units outstanding	0		50.6		0		113.4
Subordinated Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income					$ 253
Declared distributions	$ 79		$ 60		229		$ 60
Amortization of beneficial conversion feature of Class B units			(686)				(1,410)
Assumed allocation of undistributed net income	3	[1]	(53)		18	[1]	(41)
Assumed allocation of net income	$ 82		$ (679)		$ 247		$ (1,391)
Weighted average units outstanding	135.4		135.4		135.4		135.4
Basic and diluted net income (loss) per unit	$ 0.60	[2]	$ (5.02)	[2]	$ 1.82		$ (10.28)	[2]
General Partner [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income					$ 19
Declared distributions	$ 5		$ 4		17		$ 5
Amortization of beneficial conversion feature of Class B units			0				0
Assumed allocation of undistributed net income	0	[1]	(4)		1	[1]	(3)
Assumed allocation of net income	5		0		18		2
IDR [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Declared distributions	11		0		24		0
Amortization of beneficial conversion feature of Class B units			0				0
Assumed allocation of undistributed net income	0	[1]	0		0	[1]	0
Assumed allocation of net income	$ 11		$ 0		$ 24		$ 0
[1]	Under our partnership agreement, the IDRs participate in net income (loss) only to the extent of the amount of cash distributions actually declared, thereby excluding the IDRs from participating in undistributed net income (loss).
[2]	Earnings per unit in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

Customer Concentration (Details

Customer Concentration (Details)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Customer A [Member] | Total Third-Party Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	24.00%	31.00%	27.00%	42.00%
Customer A [Member] | Accounts Receivable from Third-Parties [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			28.00%		39.00%
Customer B [Member] | Total Third-Party Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	21.00%	24.00%	22.00%	26.00%
Customer B [Member] | Accounts Receivable from Third-Parties [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			26.00%		32.00%
Customer C [Member] | Total Third-Party Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	21.00%	35.00%	23.00%	18.00%
Customer C [Member] | Accounts Receivable from Third-Parties [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			22.00%		26.00%
Customer D [Member] | Total Third-Party Revenues [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	24.00%	0.00%	18.00%	0.00%
Customer D [Member] | Accounts Receivable from Third-Parties [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			19.00%		0.00%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 586	$ 459
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$ 204	$ 247

Supplemental Guarantor Inform_3

Supplemental Guarantor Information - Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 0	$ 0
Restricted cash	1,457	1,589
Accounts and other receivables	224	191
Accounts receivable—affiliate	22	163
Advances to affiliate	189	36
Inventory	88	95
Other current assets	55	65
Other current assets—affiliate	0	0
Total current assets	2,035	2,139
Property, plant and equipment, net	15,282	15,139
Debt issuance costs, net	15	38
Non-current derivative assets	25	31
Investments in subsidiaries	0	0
Other non-current assets, net	179	206
Total assets	17,536	17,553
Current liabilities
Accounts payable	13	12
Accrued liabilities	503	637
Due to affiliates	53	68
Deferred revenue	119	111
Deferred revenue—affiliate	0	1
Derivative liabilities	6	0
Other current liabilities—affiliate		0
Total current liabilities	694	829
Long-term debt, net	16,059	16,046
Non-current derivative liabilities	2	3
Other non-current liabilities	10	11
Other non-current liabilities—affiliate	23	25
Partners’ equity (deficit)	748	639
Total liabilities and partners’ equity (deficit)	17,536	17,553
Parent Issuer [Member]
Current assets
Cash and cash equivalents	0	0
Restricted cash	799	1,033
Accounts and other receivables	1	0
Accounts receivable—affiliate	1	0
Advances to affiliate	0	0
Inventory	0	0
Other current assets	19	8
Other current assets—affiliate	0	0
Total current assets	820	1,041
Property, plant and equipment, net	79	80
Debt issuance costs, net	1	20
Non-current derivative assets	9	14
Investments in subsidiaries	2,449	2,076
Other non-current assets, net	0	0
Total assets	3,358	3,231
Current liabilities
Accounts payable	1	0
Accrued liabilities	44	23
Due to affiliates	0	0
Deferred revenue	0	0
Deferred revenue—affiliate	0	0
Derivative liabilities	0
Other current liabilities—affiliate		0
Total current liabilities	45	23
Long-term debt, net	2,565	2,569
Non-current derivative liabilities	0	0
Other non-current liabilities	0	0
Other non-current liabilities—affiliate	0	0
Partners’ equity (deficit)	748	639
Total liabilities and partners’ equity (deficit)	3,358	3,231
Guarantors [Member]
Current assets
Cash and cash equivalents	0	0
Restricted cash	9	12
Accounts and other receivables	1	2
Accounts receivable—affiliate	46	36
Advances to affiliate	100	20
Inventory	12	10
Other current assets	1	3
Other current assets—affiliate	0	0
Total current assets	169	83
Property, plant and equipment, net	2,136	2,164
Debt issuance costs, net	0	0
Non-current derivative assets	0	0
Investments in subsidiaries	347	(63)
Other non-current assets, net	27	37
Total assets	2,679	2,221
Current liabilities
Accounts payable	5	4
Accrued liabilities	20	8
Due to affiliates	132	47
Deferred revenue	24	27
Deferred revenue—affiliate	21	22
Derivative liabilities	0
Other current liabilities—affiliate		1
Total current liabilities	202	109
Long-term debt, net	0	0
Non-current derivative liabilities	0	0
Other non-current liabilities	5	11
Other non-current liabilities—affiliate	23	25
Partners’ equity (deficit)	2,449	2,076
Total liabilities and partners’ equity (deficit)	2,679	2,221
Non-Guarantors [Member]
Current assets
Cash and cash equivalents	0	0
Restricted cash	649	544
Accounts and other receivables	222	189
Accounts receivable—affiliate	21	163
Advances to affiliate	174	26
Inventory	76	85
Other current assets	35	54
Other current assets—affiliate	21	21
Total current assets	1,198	1,082
Property, plant and equipment, net	13,091	12,920
Debt issuance costs, net	14	18
Non-current derivative assets	16	17
Investments in subsidiaries	0	0
Other non-current assets, net	152	169
Total assets	14,471	14,206
Current liabilities
Accounts payable	7	8
Accrued liabilities	439	606
Due to affiliates	52	66
Deferred revenue	95	84
Deferred revenue—affiliate	0	0
Derivative liabilities	6
Other current liabilities—affiliate		0
Total current liabilities	599	764
Long-term debt, net	13,494	13,477
Non-current derivative liabilities	2	3
Other non-current liabilities	5	0
Other non-current liabilities—affiliate	0	0
Partners’ equity (deficit)	371	(38)
Total liabilities and partners’ equity (deficit)	14,471	14,206
Eliminations [Member]
Current assets
Cash and cash equivalents	0	0
Restricted cash	0	0
Accounts and other receivables	0	0
Accounts receivable—affiliate	(46)	(36)
Advances to affiliate	(85)	(10)
Inventory	0	0
Other current assets	0	0
Other current assets—affiliate	(21)	(21)
Total current assets	(152)	(67)
Property, plant and equipment, net	(24)	(25)
Debt issuance costs, net	0	0
Non-current derivative assets	0	0
Investments in subsidiaries	(2,796)	(2,013)
Other non-current assets, net	0	0
Total assets	(2,972)	(2,105)
Current liabilities
Accounts payable	0	0
Accrued liabilities	0	0
Due to affiliates	(131)	(45)
Deferred revenue	0	0
Deferred revenue—affiliate	(21)	(21)
Derivative liabilities	0
Other current liabilities—affiliate		(1)
Total current liabilities	(152)	(67)
Long-term debt, net	0	0
Non-current derivative liabilities	0	0
Other non-current liabilities	0	0
Other non-current liabilities—affiliate	0	0
Partners’ equity (deficit)	(2,820)	(2,038)
Total liabilities and partners’ equity (deficit)	$ (2,972)	$ (2,105)

Supplemental Guarantor Inform_4

Supplemental Guarantor Information - Condensed Consolidating Statements of Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues
Revenue earned from contracts with customers	$ 1,465	$ 897	$ 4,412	$ 2,763
Revenues	1,529	903	4,529	2,786
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	756	490	2,291	1,580
Cost of sales—affiliate	0	0	0	0
Operating and maintenance expense	113	73	306	205
Operating and maintenance expense—affiliate	31	31	87	70
Development expense	1	1	2	2
General and administrative expense	3	5	9	10
General and administrative expense—affiliate	18	18	53	63
Depreciation and amortization expense	107	87	318	239
Other	0	1	0	1
Impairment expense and loss on disposal of assets	8	0	8	0
Total operating costs and expenses	1,037	706	3,074	2,170
Income (loss) from operations	492	197	1,455	616
Other income (expense)
Interest expense, net of capitalized interest	(183)	(153)	(552)	(437)
Loss on modification or extinguishment of debt	(12)	(25)	(12)	(67)
Derivative gain (loss), net	2	1	13	(2)
Equity earnings (losses) of subsidiaries	0	0	0	0
Other income	8	3	19	6
Total other income (expense)	(185)	(174)	(532)	(500)
Net income (loss)	307	23	923	116
LNG [Member]
Revenues
Revenue earned from contracts with customers	1,185	717	3,302	1,695
Revenues	1,249	723	3,419	1,718
LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	205	111	886	864
Regasification [Member]
Revenues
Revenue earned from contracts with customers	66	65	196	195
Regasification—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Other [Member]
Revenues
Revenue earned from contracts with customers	9	3	28	7
Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	1	0	2
Parent Issuer [Member]
Revenues
Revenues	0	0	0	0
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	0	0	0	0
Cost of sales—affiliate	0	0	0	0
Operating and maintenance expense	0	1	0	4
Operating and maintenance expense—affiliate	0	6	0	6
Development expense	0	0	0	0
General and administrative expense	1	1	3	3
General and administrative expense—affiliate	3	3	9	9
Depreciation and amortization expense	1	1	2	1
Other		0		0
Impairment expense and loss on disposal of assets	0		0
Total operating costs and expenses	5	12	14	23
Income (loss) from operations	(5)	(12)	(14)	(23)
Other income (expense)
Interest expense, net of capitalized interest	(36)	(29)	(104)	(81)
Loss on modification or extinguishment of debt	(12)	(25)	(12)	(25)
Derivative gain (loss), net	2	1	13	0
Equity earnings (losses) of subsidiaries	354	88	1,030	244
Other income	4	0	10	1
Total other income (expense)	312	35	937	139
Net income (loss)	307	23	923	116
Parent Issuer [Member] | LNG [Member]
Revenues
Revenues	0	0	0	0
Parent Issuer [Member] | LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Parent Issuer [Member] | Regasification [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Parent Issuer [Member] | Regasification—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Parent Issuer [Member] | Other [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Parent Issuer [Member] | Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Guarantors [Member]
Revenues
Revenues	187	167	601	492
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	0	(1)	2	1
Cost of sales—affiliate	0	0	0	0
Operating and maintenance expense	17	7	48	29
Operating and maintenance expense—affiliate	39	33	113	96
Development expense	1	0	1	0
General and administrative expense	1	1	2	2
General and administrative expense—affiliate	6	6	17	19
Depreciation and amortization expense	19	17	56	55
Other		1		1
Impairment expense and loss on disposal of assets	8		8
Total operating costs and expenses	91	64	247	203
Income (loss) from operations	96	103	354	289
Other income (expense)
Interest expense, net of capitalized interest	(1)	0	(3)	0
Loss on modification or extinguishment of debt	0	0	0	0
Derivative gain (loss), net	0	0	0	0
Equity earnings (losses) of subsidiaries	243	(12)	678	(36)
Other income	(1)	0	0	0
Total other income (expense)	241	(12)	675	(36)
Net income (loss)	337	91	1,029	253
Guarantors [Member] | LNG [Member]
Revenues
Revenues	0	0	0	0
Guarantors [Member] | LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Guarantors [Member] | Regasification [Member]
Revenues
Revenue earned from contracts with customers	66	65	196	195
Guarantors [Member] | Regasification—affiliate [Member]
Revenues
Revenue earned from contracts with customers	64	48	194	128
Guarantors [Member] | Other [Member]
Revenues
Revenue earned from contracts with customers	9	3	28	7
Guarantors [Member] | Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	48	51	183	162
Non-Guarantors [Member]
Revenues
Revenues	1,454	834	4,305	2,582
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	758	488	2,291	1,576
Cost of sales—affiliate	8	5	23	15
Operating and maintenance expense	96	65	258	172
Operating and maintenance expense—affiliate	107	82	317	224
Development expense	0	1	1	2
General and administrative expense	1	3	4	5
General and administrative expense—affiliate	12	12	36	46
Depreciation and amortization expense	88	69	261	183
Other		0		0
Impairment expense and loss on disposal of assets	0		0
Total operating costs and expenses	1,070	725	3,191	2,223
Income (loss) from operations	384	109	1,114	359
Other income (expense)
Interest expense, net of capitalized interest	(146)	(124)	(445)	(356)
Loss on modification or extinguishment of debt	0	0	0	(42)
Derivative gain (loss), net	0	0	0	(2)
Equity earnings (losses) of subsidiaries	0	0	0	0
Other income	5	3	9	5
Total other income (expense)	(141)	(121)	(436)	(395)
Net income (loss)	243	(12)	678	(36)
Non-Guarantors [Member] | LNG [Member]
Revenues
Revenues	1,249	723	3,419	1,718
Non-Guarantors [Member] | LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	205	111	886	864
Non-Guarantors [Member] | Regasification [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Non-Guarantors [Member] | Regasification—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Non-Guarantors [Member] | Other [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Non-Guarantors [Member] | Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Eliminations [Member]
Revenues
Revenues	(112)	(98)	(377)	(288)
Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	(2)	3	(2)	3
Cost of sales—affiliate	(8)	(5)	(23)	(15)
Operating and maintenance expense	0	0	0	0
Operating and maintenance expense—affiliate	(115)	(90)	(343)	(256)
Development expense	0	0	0	0
General and administrative expense	0	0	0	0
General and administrative expense—affiliate	(3)	(3)	(9)	(11)
Depreciation and amortization expense	(1)	0	(1)	0
Other		0		0
Impairment expense and loss on disposal of assets	0		0
Total operating costs and expenses	(129)	(95)	(378)	(279)
Income (loss) from operations	17	(3)	1	(9)
Other income (expense)
Interest expense, net of capitalized interest	0	0	0	0
Loss on modification or extinguishment of debt	0	0	0	0
Derivative gain (loss), net	0	0	0	0
Equity earnings (losses) of subsidiaries	(597)	(76)	(1,708)	(208)
Other income	0	0	0	0
Total other income (expense)	(597)	(76)	(1,708)	(208)
Net income (loss)	(580)	(79)	(1,707)	(217)
Eliminations [Member] | LNG [Member]
Revenues
Revenues	0	0	0	0
Eliminations [Member] | LNG—affiliate [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Eliminations [Member] | Regasification [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Eliminations [Member] | Regasification—affiliate [Member]
Revenues
Revenue earned from contracts with customers	(64)	(48)	(194)	(128)
Eliminations [Member] | Other [Member]
Revenues
Revenue earned from contracts with customers	0	0	0	0
Eliminations [Member] | Other—affiliate [Member]
Revenues
Revenue earned from contracts with customers	$ (48)	$ (50)	$ (183)	$ (160)

Supplemental Guarantor Inform_5

Supplemental Guarantor Information - Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	$ 1,264	$ 513
Cash flows from investing activities
Property, plant and equipment, net	(578)	(1,195)
Investments in subsidiaries	0	0
Distributions received from affiliates, net	0	0
Net cash provided by (used in) investing activities	(578)	(1,195)
Cash flows from financing activities
Proceeds from issuances of debt	1,100	3,814
Repayments of debt	(1,090)	(2,173)
Debt issuance and deferred financing costs	(8)	(47)
Debt extinguishment costs	(6)	0
Distributions to parent	0	0
Contributions from parent	0	0
Distributions to owners	(814)	(74)
Net cash provided by (used in) financing activities	(818)	1,520
Net increase (decrease) in cash, cash equivalents and restricted cash	(132)	838
Cash, cash equivalents and restricted cash—beginning of period	1,589	605
Cash, cash equivalents and restricted cash—end of period	1,457	1,443
Parent Issuer [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	339	(89)
Cash flows from investing activities
Property, plant and equipment, net	0	0
Investments in subsidiaries	(202)	(216)
Distributions received from affiliates, net	447	929
Net cash provided by (used in) investing activities	245	713
Cash flows from financing activities
Proceeds from issuances of debt	1,100	1,500
Repayments of debt	(1,090)	(1,470)
Debt issuance and deferred financing costs	(8)	(18)
Debt extinguishment costs	(6)
Distributions to parent	0	0
Contributions from parent	0	0
Distributions to owners	(814)	(74)
Net cash provided by (used in) financing activities	(818)	(62)
Net increase (decrease) in cash, cash equivalents and restricted cash	(234)	562
Cash, cash equivalents and restricted cash—beginning of period	1,033	234
Cash, cash equivalents and restricted cash—end of period	799	796
Guarantors [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	408	293
Cash flows from investing activities
Property, plant and equipment, net	(24)	(16)
Investments in subsidiaries	(81)	(7)
Distributions received from affiliates, net	350	450
Net cash provided by (used in) investing activities	245	427
Cash flows from financing activities
Proceeds from issuances of debt	0	0
Repayments of debt	0	0
Debt issuance and deferred financing costs	0	0
Debt extinguishment costs	0
Distributions to parent	(858)	(929)
Contributions from parent	202	216
Distributions to owners	0	0
Net cash provided by (used in) financing activities	(656)	(713)
Net increase (decrease) in cash, cash equivalents and restricted cash	(3)	7
Cash, cash equivalents and restricted cash—beginning of period	12	13
Cash, cash equivalents and restricted cash—end of period	9	20
Non-Guarantors [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	928	317
Cash flows from investing activities
Property, plant and equipment, net	(554)	(1,187)
Investments in subsidiaries	0	0
Distributions received from affiliates, net	0	0
Net cash provided by (used in) investing activities	(554)	(1,187)
Cash flows from financing activities
Proceeds from issuances of debt	0	2,314
Repayments of debt	0	(703)
Debt issuance and deferred financing costs	0	(29)
Debt extinguishment costs	0
Distributions to parent	(350)	(450)
Contributions from parent	81	7
Distributions to owners	0	0
Net cash provided by (used in) financing activities	(269)	1,139
Net increase (decrease) in cash, cash equivalents and restricted cash	105	269
Cash, cash equivalents and restricted cash—beginning of period	544	358
Cash, cash equivalents and restricted cash—end of period	649	627
Eliminations [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(411)	(8)
Cash flows from investing activities
Property, plant and equipment, net	0	8
Investments in subsidiaries	283	223
Distributions received from affiliates, net	(797)	(1,379)
Net cash provided by (used in) investing activities	(514)	(1,148)
Cash flows from financing activities
Proceeds from issuances of debt	0	0
Repayments of debt	0	0
Debt issuance and deferred financing costs	0	0
Debt extinguishment costs	0
Distributions to parent	1,208	1,379
Contributions from parent	(283)	(223)
Distributions to owners	0	0
Net cash provided by (used in) financing activities	925	1,156
Net increase (decrease) in cash, cash equivalents and restricted cash	0	0
Cash, cash equivalents and restricted cash—beginning of period	0	0
Cash, cash equivalents and restricted cash—end of period	$ 0	$ 0

Supplemental Guarantor Inform_6

Supplemental Guarantor Information Supplemental Guarantor Information - Condensed Consolidating Cash Flows - Balances per Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	$ 0	$ 0
Restricted cash	1,457	1,589
Total cash, cash equivalents and restricted cash	1,457	1,589	$ 1,443	$ 605
Parent Issuer [Member]
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	0	0
Restricted cash	799	1,033
Total cash, cash equivalents and restricted cash	799	1,033	796	234
Guarantors [Member]
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	0	0
Restricted cash	9	12
Total cash, cash equivalents and restricted cash	9	12	20	13
Non-Guarantors [Member]
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	0	0
Restricted cash	649	544
Total cash, cash equivalents and restricted cash	649	544	627	358
Eliminations [Member]
Balances per Consolidated Balance Sheet:
Cash and cash equivalents	0	0
Restricted cash	0	0
Total cash, cash equivalents and restricted cash	$ 0	$ 0	$ 0	$ 0