Cheniere Energy Partners (CQP) 10-Q 2 Nov 22 2022 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2022	Oct. 31, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	001-33366
Entity Registrant Name	Cheniere Energy Partners, L.P.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-5913059
Entity Address, Address Line One	700 Milam Street
Entity Address, Address Line Two	Suite 1900
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	375-5000
Title of 12(b) Security	Common Units Representing Limited Partner Interests
Trading Symbol	CQP
Security Exchange Name	NYSEAMER
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Units, Units Outstanding		484,031,623
Entity Central Index Key	0001383650
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues
Revenues	$ 4,976	$ 2,324	$ 12,485	$ 6,176
Revenues from contracts with customers	4,979	2,324	12,484	6,176
Operating costs and expenses
Cost of sales (excluding items shown separately below)	4,739	1,342	10,445	3,178
Cost of sales—affiliate	104	8	166	62
Cost of sales—related party	0	0	1	1
Operating and maintenance expense	189	148	550	465
Operating and maintenance expense—affiliate	39	34	118	103
Operating and maintenance expense—related party	18	12	45	34
General and administrative expense	3	2	3	7
General and administrative expense—affiliate	23	22	70	64
Depreciation and amortization expense	160	140	469	417
Other	0	0	0	7
Total operating costs and expenses	5,275	1,708	11,867	4,338
Income (loss) from operations	(299)	616	618	1,838
Other income (expense)
Interest expense, net of capitalized interest	(222)	(210)	(641)	(636)
Loss on modification or extinguishment of debt	0	(27)	0	(81)
Other income, net	7	2	10	2
Total other expense	(215)	(235)	(631)	(715)
Net income (loss)	$ (514)	$ 381	$ (13)	$ 1,123
Net Income (Loss), Per Outstanding Limited Partnership and General Partnership Unit, Basic and Diluted, Net of Tax	$ (1.49)	$ 0.69	$ (1.36)	$ 2.07
Weighted average units outstanding	484	484	484	484
LNG [Member]
Revenues
Revenues	$ 3,130	$ 1,791	$ 8,577	$ 5,057
Revenues from contracts with customers	3,133	1,791	8,576	5,057
LNG—affiliate [Member]
Revenues
Revenues from contracts with customers	1,376	453	3,268	878
LNG—related party[Member]
Revenues
Revenues from contracts with customers	0	0	4	0
Regasification [Member]
Revenues
Revenues from contracts with customers	455	68	591	202
Other [Member]
Revenues
Revenues from contracts with customers	$ 15	$ 12	$ 45	$ 39

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Current assets
Cash and cash equivalents	$ 988	$ 876
Restricted cash and cash equivalents	195	98
Trade and other receivables, net of current expected credit losses	805	580
Accounts receivable—affiliate	447	232
Accounts receivable—related party	0	1
Advances to affiliate	150	141
Inventory	241	176
Current derivative assets	27	21
Margin deposits	59	7
Contract assets	387	0
Other current assets	74	80
Total current assets	3,373	2,212
Property, plant and equipment, net of accumulated depreciation	16,827	16,830
Operating lease assets	91	98
Debt issuance costs, net of accumulated amortization	9	12
Derivative assets	33	33
Other non-current assets, net	167	173
Total assets	20,500	19,358
Current liabilities
Accounts payable	31	21
Accrued liabilities	1,657	1,073
Accrued liabilities—related party	8	4
Current debt, net of discount and debt issuance costs	1,498	0
Due to affiliates	56	67
Deferred revenue	162	155
Deferred revenue—affiliate	1	1
Current operating lease liabilities	9	8
Current derivative liabilities	1,157	16
Other current liabilities	4	0
Total current liabilities	4,583	1,345
Long-term debt, net of premium, discount and debt issuance costs	15,699	17,177
Operating lease liabilities	82	89
Finance lease liabilities	18	0
Derivative liabilities	3,981	11
Other non-current liabilities—affiliate	21	18
Partners’ equity (deficit)
Common unitholders’ interest (484.0 million units issued and outstanding at both September 30, 2022 and December 31, 2021)	(3,059)	1,024
General partner’s interest (2% interest with 9.9 million units issued and outstanding at September 30, 2022 and December 31, 2021)	(825)	(306)
Total partners’ equity (deficit)	(3,884)	718
Total liabilities and partners’ equity (deficit)	$ 20,500	$ 19,358

Consolidated Balance Sheets Par

Consolidated Balance Sheets Parentheticals - shares shares in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2021	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020
Cheniere Partners [Member]
General Partner Ownership Interest Percentage	2%	2%
Common Units [Member]
Limited Partners' Capital Account, Units Outstanding	484	484	484	484	484	484	484	484
General Partner [Member]
General Partners' Capital Account, Units Outstanding	9.9	9.9	9.9	9.9	9.9	9.9	9.9	9.9

Consolidated Statements of Part

Consolidated Statements of Partners' Equity - USD ($) shares in Millions, $ in Millions	Total	Common Units [Member]	General Partner [Member]
Units, Outstanding, beginning of period at Dec. 31, 2020		484
Partners' equity, beginning of period at Dec. 31, 2020	$ 539	$ 714	$ (175)
General partner units, Outstanding, beginning of period at Dec. 31, 2020			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	347	340	$ 7
Distributions		$ (316)	(35)
Units, Outstanding, end of period at Mar. 31, 2021		484
Partners' equity, end of period at Mar. 31, 2021	535	$ 738	$ (203)
General partner units, Outstanding, end of period at Mar. 31, 2021			9.9
Units, Outstanding, beginning of period at Dec. 31, 2020		484
Partners' equity, beginning of period at Dec. 31, 2020	539	$ 714	$ (175)
General partner units, Outstanding, beginning of period at Dec. 31, 2020			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	1,123
Units, Outstanding, end of period at Sep. 30, 2021		484
Partners' equity, end of period at Sep. 30, 2021	589	$ 856	$ (267)
General partner units, Outstanding, end of period at Sep. 30, 2021			9.9
Units, Outstanding, beginning of period at Mar. 31, 2021		484
Partners' equity, beginning of period at Mar. 31, 2021	535	$ 738	$ (203)
General partner units, Outstanding, beginning of period at Mar. 31, 2021			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	395	387	$ 8
Distributions		$ (320)	(39)
Units, Outstanding, end of period at Jun. 30, 2021		484
Partners' equity, end of period at Jun. 30, 2021	571	$ 805	$ (234)
General partner units, Outstanding, end of period at Jun. 30, 2021			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	381	373	$ 8
Distributions		$ (322)	(41)
Units, Outstanding, end of period at Sep. 30, 2021		484
Partners' equity, end of period at Sep. 30, 2021	589	$ 856	$ (267)
General partner units, Outstanding, end of period at Sep. 30, 2021			9.9
Units, Outstanding, beginning of period at Dec. 31, 2021		484
Partners' equity, beginning of period at Dec. 31, 2021	718	$ 1,024	$ (306)
General partner units, Outstanding, beginning of period at Dec. 31, 2021			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	159	157	$ 2
Novated IPM Agreement	(2,712)	(2,712)
Distributions		$ (339)	(56)
Units, Outstanding, end of period at Mar. 31, 2022		484
Partners' equity, end of period at Mar. 31, 2022	(2,230)	$ (1,870)	$ (360)
General partner units, Outstanding, end of period at Mar. 31, 2022			9.9
Units, Outstanding, beginning of period at Dec. 31, 2021		484
Partners' equity, beginning of period at Dec. 31, 2021	718	$ 1,024	$ (306)
General partner units, Outstanding, beginning of period at Dec. 31, 2021			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	(13)
Units, Outstanding, end of period at Sep. 30, 2022		484
Partners' equity, end of period at Sep. 30, 2022	(3,884)	$ (3,059)	$ (825)
General partner units, Outstanding, end of period at Sep. 30, 2022			9.9
Units, Outstanding, beginning of period at Mar. 31, 2022		484
Partners' equity, beginning of period at Mar. 31, 2022	(2,230)	$ (1,870)	$ (360)
General partner units, Outstanding, beginning of period at Mar. 31, 2022			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	342	335	$ 7
Distributions		$ (508)	(229)
Units, Outstanding, end of period at Jun. 30, 2022		484
Partners' equity, end of period at Jun. 30, 2022	(2,625)	$ (2,043)	$ (582)
General partner units, Outstanding, end of period at Jun. 30, 2022			9.9
Increase (Decrease) in Partners' Capital [Roll Forward]
Net Income (Loss)	(514)	(503)	$ (11)
Distributions		$ (513)	(232)
Units, Outstanding, end of period at Sep. 30, 2022		484
Partners' equity, end of period at Sep. 30, 2022	$ (3,884)	$ (3,059)	$ (825)
General partner units, Outstanding, end of period at Sep. 30, 2022			9.9

Consolidated Statements of Pa_2

Consolidated Statements of Partners' Equity Parentheticals - $ / shares	3 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021
Common Units [Member]
Distributions Paid, Per Unit	$ 1.06	$ 1.05	$ 0.700	$ 0.665	$ 0.660	$ 0.655

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Cash flows from operating activities
Net income (loss)	$ (13)	$ 1,123
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	469	417
Amortization of debt issuance costs, premium and discount	22	22
Loss on modification or extinguishment of debt	0	81
Total losses (gains) on derivative instruments, net	2,447	(64)
Net cash provided by (used for) settlement of derivative instruments	(54)	10
Other	28	19
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	(290)	(41)
Accounts receivable—affiliate	(231)	(13)
Advances to affiliate	(10)	11
Inventory	(67)	(26)
Margin deposits	(52)	(25)
Contract assets	(387)	0
Accounts payable and accrued liabilities	592	165
Accrued liabilities—related party	5	1
Due to affiliates	2	(6)
Deferred revenue	6	29
Other, net	(30)	(37)
Other, net—affiliate	5	1
Net cash provided by operating activities	2,442	1,667
Cash flows from investing activities
Property, plant and equipment	(356)	(495)
Net cash used in investing activities	(356)	(495)
Cash flows from financing activities
Proceeds from issuances of debt	0	2,700
Redemptions and repayments of debt	0	(2,172)
Debt issuance and other financing costs	0	(35)
Debt extinguishment costs	0	(61)
Distributions	(1,877)	(1,073)
Other	0	8
Net cash used in financing activities	(1,877)	(633)
Net increase in cash, cash equivalents and restricted cash and cash equivalents	209	539
Cash, Cash Equivalents—beginning of period	974	1,307
Cash, Cash Equivalents—end of period	$ 1,183	$ 1,846

Consolidated Statements of Ca_2

Consolidated Statements of Cash Flows - Balances per Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020
Balances per Consolidated Balance Sheets:
Cash and cash equivalents	$ 988	$ 876
Restricted cash and cash equivalents	195	98
Total cash, cash equivalents and restricted cash and cash equivalents	$ 1,183	$ 974	$ 1,846	$ 1,307

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We own the natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal”) which has six operational Trains, with Train 6 having achieved substantial completion on February 4, 2022, for a total production capacity of approximately 30 mtpa of LNG (the “Liquefaction Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include five LNG storage tanks, vaporizers and three marine berths, with the third berth having achieved substantial completion on October 27, 2022. We also own a 94-mile pipeline through our subsidiary, CTPL, that interconnects the Sabine Pass LNG Terminal with a number of large interstate and intrastate pipelines (the “Creole Trail Pipeline”). We have increased available liquefaction capacity at our Liquefaction Project as a result of debottlenecking and other optimization projects. We hold a significant land position at the Sabine Pass LNG Terminal, which provides opportunity for further liquefaction capacity expansion. The development of this site or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a positive final investment decision. As of September 30, 2022, Cheniere owned 48.6% of our limited partner interest in the form of 239.9 million of our common units. Cheniere also owns 100% of our general partner interest and our incentive distribution rights (“IDRs”). Basis of Presentation The accompanying unaudited Consolidated Financial Statements of CQP have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the financial results for the interim periods presented. 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 fiscal year ended December 31, 2021 . Results of operations for the three and nine months ended September 30, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022. 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. Recent Accounting Standards ASU 2020-04 In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting . This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The standard is effective from March 12, 2020 to December 31, 2022. We have not yet applied the optional expedients available under the standard because we have not yet modified any of our existing contracts indexed to LIBOR, mainly our credit facilities as further described in Note 9—Debt

Unitholders' Equity

Unitholders' Equity	9 Months Ended
	Sep. 30, 2022
Partners' Capital Notes [Abstract]
Unitholders' Equity	UNITHOLDERS’ EQUITY The common units represent limited partner interests in us, which entitle the unitholders to participate in partnership distributions and exercise the rights and privileges available to limited partners under our partnership agreement. Although common unitholders are not obligated to fund losses of the Partnership, their capital account, which would be considered in allocating the net assets of the Partnership were it to be liquidated, continues 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 IDRs, which allow the general partner to receive a higher percentage of quarterly distributions of available cash from operating surplus 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. 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 we have paid to date have been made from accumulated operating surplus as defined in the partnership agreement. As of September 30, 2022, our total securities beneficially owned in the form of common units were held 48.6% by Cheniere, 41.4% by CQP Target Holdco L.L.C. (“CQP Target Holdco”) and other affiliates of Blackstone Inc. (“Blackstone”) and Brookfield Asset Management Inc. (“Brookfield”) and 8.0% by the public. All of our 2% general partner interest was held by Cheniere. CQP Target Holdco’s equity interests are 50.0% owned by BIP Chinook Holdco L.L.C., an affiliate of Blackstone, and 50.0% owned by BIF IV Cypress Aggregator (Delaware) LLC, an affiliate of Brookfield. The ownership of CQP Target Holdco, Blackstone and Brookfield are based on their most recent filings with the SEC.

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	9 Months Ended
	Sep. 30, 2022
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS Restricted cash and cash equivalents consist of funds that are contractually or legally restricted as to usage or withdrawal. As of September 30, 2022 and December 31, 2021, we had $195 million and $98 million of restricted cash and cash equivalents, respectively.

Trade and Other Receivables, Ne

Trade and Other Receivables, Net of Current Expected Credit Losses	9 Months Ended
	Sep. 30, 2022
Receivables [Abstract]
Trade and Other Receivables, Net of Current Expected Credit Losses	TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2022 2021 Trade receivables $ 761 $ 546 Other receivables 44 34 Total trade and other receivables, net of current expected credit losses $ 805 $ 580

Inventory

Inventory	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Inventory	INVENTORY Inventory consisted of the following (in millions): September 30, December 31, 2022 2021 Materials $ 100 $ 86 LNG 107 45 Natural gas 32 43 Other 2 2 Total inventory $ 241 $ 176

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2022 2021 LNG terminal Terminal and interconnecting pipeline facilities $ 19,459 $ 16,973 Construction-in-process 699 2,746 Accumulated depreciation (3,356) (2,893) Total LNG terminal, net of accumulated depreciation 16,802 16,826 Fixed assets Fixed assets 29 29 Accumulated depreciation (26) (25) Total fixed assets, net of accumulated depreciation 3 4 Assets under finance lease Tug vessels 23 — Accumulated depreciation (1) — Total assets under finance lease, net of accumulated depreciation 22 — Property, plant and equipment, net of accumulated depreciation $ 16,827 $ 16,830 The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Depreciation expense $ 158 $ 139 $ 465 $ 414 Offsets to LNG terminal costs (1) — — 148 —

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into commodity derivatives consisting of natural gas supply contracts, including those under SPL’s IPM agreement, for the operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”). 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 or fair value hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process, in which case such changes are capitalized. The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis (in millions): Fair Value Measurements as of September 30, 2022 December 31, 2021 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Liquefaction Supply Derivatives asset (liability) $ (30) $ (24) $ (5,024) $ (5,078) $ 2 $ (13) $ 38 $ 27 We value our Liquefaction Supply Derivatives using a market or option-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data. The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated events deriving fair value including, but not limited to, evaluation of whether the respective market exists from the perspective of market participants as infrastructure is developed. 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 incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity and volatility. The Level 3 fair value measurements of natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(5,024) Market approach incorporating present value techniques Henry Hub basis spread $(2.495) - $0.677 / $(0.028) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 91% - 865% / 243% (1) Unobservable inputs were weighted by the relative fair value of the instruments. (2) Spread contemplates U.S. dollar-denominated pricing. Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Physical Liquefaction Supply Derivatives. The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Balance, beginning of period $ (3,456) $ 33 $ 38 $ (21) Realized and mark-to-market gains (losses): Included in cost of sales (1,545) 25 (155) 79 Purchases and settlements: Purchases (1) 3 4 (4,896) 6 Settlements (24) (3) (11) (5) Transfers out of Level 3, net (2) (2) — — — Balance, end of period $ (5,024) $ 59 $ (5,024) $ 59 Change in unrealized gains (losses) relating to instruments still held at end of period $ (1,545) $ 25 $ (155) $ 79 (1) Includes the assignment of an IPM agreement that occurred during the period, as discussed in Note 1 4 —Supplemental Cash Flow Information . (2) Transferred out of Level 3 as a result of unobservable market for the underlying natural gas purchase agreements. All counterparty derivative contracts provide for the unconditional right of set-off in the event of default. We have elected to report derivative assets and liabilities arising from our derivative contracts with the same counterparty and the unconditional contractual right of set-off on a net basis. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments, in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements depending on the position of the derivative. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees. Liquefaction Supply Derivatives SPL holds Liquefaction Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. The remaining minimum terms of the Physical Liquefaction Supply Derivatives range up to 15 years, some of which commence upon the satisfaction of certain events or states of affairs. The terms of the Financial Liquefaction Supply Derivatives range up to approximately three years. The forward notional amount for our Liquefaction Supply Derivatives was approximately 5,220 TBtu and 5,194 TBtu as of September 30, 2022 and December 31, 2021, respectively, excluding notional amounts associated with extension options that were uncertain to be taken as of September 30, 2022. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues $ (3) $ — $ 1 $ — Cost of sales (1,625) 10 (2,448) 64 (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. Fair Value and Location of Derivative Assets and Liabilities on the Consolidated Balance Sheets 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 Sheets Location September 30, 2022 December 31, 2021 Current derivative assets $ 27 $ 21 Derivative assets 33 33 Total derivative assets 60 54 Current derivative liabilities (1,157) (16) Derivative liabilities (3,981) (11) Total derivative liabilities (5,138) (27) Derivative asset (liability), net $ (5,078) $ 27 (1) Does not include collateral posted with counterparties by us of $59 million and $7 million, as of September 30, 2022 and December 31, 2021, respectively, which are included in other current assets in our Consolidated Balance Sheets. Consolidated Balance Sheets Presentation The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions) for our derivative instruments that are presented on a net basis on our Consolidated Balance Sheets: Liquefaction Supply Derivatives As of September 30, 2022 Gross assets $ 67 Offsetting amounts (7) Net assets $ 60 Gross liabilities $ (5,158) Offsetting amounts 20 Net liabilities $ (5,138) As of December 31, 2021 Gross assets $ 79 Offsetting amounts (25) Net assets $ 54 Gross liabilities $ (33) Offsetting amounts 6 Net liabilities $ (27)

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2022
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of the following (in millions): September 30, December 31, 2022 2021 Natural gas purchases $ 1,259 $ 786 Interest costs and related debt fees 201 180 LNG terminal and related pipeline costs 172 101 Other accrued liabilities 25 6 Total accrued liabilities $ 1,657 $ 1,073

Debt

Debt	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt	DEBT Debt consisted of the following (in millions): September 30, December 31, 2022 2021 SPL: Senior Secured Notes: 5.625% due 2023 (the “2023 SPL Senior Notes”) (1) $ 1,500 $ 1,500 5.75% due 2024 2,000 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.27% weighted average rate due 2037 1,282 1,282 Total SPL Senior Secured Notes 13,132 13,132 Working capital revolving credit and letter of credit reimbursement agreement (the “SPL Working Capital Facility”) — — Total debt - SPL 13,132 13,132 CQP: Senior Notes: 4.500% due 2029 1,500 1,500 4.000% due 2031 1,500 1,500 3.25% due 2032 1,200 1,200 Total CQP Senior Notes 4,200 4,200 Credit facilities (the “CQP Credit Facilities”) — — Total debt - CQP 4,200 4,200 Total debt 17,332 17,332 Short-term debt (1,498) — Unamortized premium, discount and debt issuance costs, net (135) (155) Total long-term debt, net of premium, discount and debt issuance costs $ 15,699 $ 17,177 (1) In October 2022, $300 million of the 2023 SPL Senior Notes were redeemed. As of September 30, 2022, the entire amount of the 2023 SPL Senior Notes was classified as short-term debt. Credit Facilities Below is a summary of our credit facilities outstanding as of September 30, 2022 (in millions): SPL Working Capital Facility CQP Credit Facilities Total facility size $ 1,200 $ 750 Less: Outstanding balance — — Letters of credit issued 363 — Available commitment $ 837 $ 750 Priority ranking Senior secured Senior secured Interest rate on available balance LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125% Commitment fees on undrawn balance 0.15% 0.49% Maturity date March 19, 2025 May 29, 2024 Restrictive Debt Covenants The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit us and our restricted subsidiaries’ ability to make certain investments or pay dividends or distributions. We and SPL are restricted from making distributions under agreements governing our and SPL’s indebtedness generally until, among other requirements, deposits are made into any required debt service reserve accounts and a historical debt service coverage ratio and projected debt service coverage ratio of at least 1.25:1.00 is satisfied. As of September 30, 2022, we and SPL were in compliance with all covenants related to our respective debt agreements. Interest Expense Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Total interest cost $ 231 $ 244 $ 678 $ 732 Capitalized interest (9) (34) (37) (96) Total interest expense, net of capitalized interest $ 222 $ 210 $ 641 $ 636 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 16,050 $ 15,036 $ 16,050 $ 17,496 Senior notes — Level 3 (2) 1,282 1,119 1,282 1,466 (1) The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. The estimated fair value of our credit facilities approximates the principal amount outstanding 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

Revenues	9 Months Ended
	Sep. 30, 2022
Revenue from Contract with Customer [Abstract]
Revenues	REVENUES The following table represents a disaggregation of revenue earned (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Revenues from contracts with customers LNG revenues $ 3,133 $ 1,791 $ 8,576 $ 5,057 LNG revenues—affiliate 1,376 453 3,268 878 LNG revenues—related party — — 4 — Regasification revenues 455 68 591 202 Other revenues 15 12 45 39 Total revenues from contracts with customers 4,979 2,324 12,484 6,176 Net derivative gain (loss) (1) (3) — 1 — Total revenues $ 4,976 $ 2,324 $ 12,485 $ 6,176 (1) See Note 7—Derivative Instruments for additional information about our derivatives. Contract Assets and Liabilities The following table shows our contract assets, net of current expected credit losses, which are classified as contract assets and other non-current assets, net on our Consolidated Balance Sheets (in millions): September 30, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 388 $ 1 The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue, beginning of period $ 155 Cash received but not yet recognized in revenue 162 Revenue recognized from prior period deferral (155) Deferred revenue, end of period $ 162 The following table reflects the changes in our contract liabilities to affiliate, which we classify as deferred revenue—affiliate and other non-current liabilities—affiliate on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue—affiliate, beginning of period $ 3 Cash received but not yet recognized in revenue 6 Revenue recognized from prior year end deferral (3) Deferred revenue—affiliate, end of period $ 6 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: September 30, 2022 December 31, 2021 Unsatisfied Weighted Average Recognition Timing (years) (1) Unsatisfied Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.6 8 $ 49.3 9 LNG revenues—affiliate 2.0 2 2.1 3 Regasification revenues 1.6 2 1.9 4 Total revenues $ 55.2 $ 53.3 (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) The table above excludes substantially all variable consideration under our SPAs and TUAs. 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 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. Certain of our contracts contain additional variable consideration based on the outcome of contingent events and the movement of various indexes. We have not included such variable consideration in the transaction price to the extent the consideration is considered constrained due to the uncertainty of ultimate pricing and receipt. Approximately 78% and 63% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2022 and 2021, respectively, and approximately 74% and 56% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2022 and 2021, respectively, were related to variable consideration received from customers. Approximately 77% and 96% of our LNG revenues—affiliate from contracts included in the table above during the three months ended September 30, 2022 and 2021, respectively, and approximately 76% and 94% of our LNG revenues—affiliate from contracts included in the table above during the nine months ended September 30, 2022 and 2021, respectively, were related to variable consideration received from customers. During the three and nine months ended September 30, 2022, approximately 1% and 2%, respectively, of our regasification revenues were related to variable consideration received from customers, and during each of the three and nine months ended September 30, 2021, approximately 5% of our regasification revenues were related to variable consideration received from customers. We may enter 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. Termination Agreement with Chevron

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2022
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 Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 1,328 $ 441 $ 3,173 $ 860 Contracts for Sale and Purchase of Natural Gas and LNG 48 12 95 18 Total LNG revenues—affiliate 1,376 453 3,268 878 LNG revenues—related party Natural Gas Transportation and Storage Agreements — — 4 — Cost of sales—affiliate Cheniere Marketing Agreements — — — 34 Contracts for Sale and Purchase of Natural Gas and LNG 104 8 166 28 Total cost of sales—affiliate 104 8 166 62 Cost of sales—related party Natural Gas Transportation and Storage Agreements — — 1 1 Operating and maintenance expense—affiliate Services Agreements 39 34 118 103 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 18 12 45 34 General and administrative expense—affiliate Services Agreements 23 22 70 64 As of September 30, 2022 and December 31, 2021, we had $447 million and $232 million, respectively, of accounts receivable—affiliate under the agreements described below. Cheniere Marketing Agreements Cheniere Marketing SPA Cheniere Marketing has an SPA (“Base 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. The Base SPA was subsequently amended to remove certain conditions related to the sale of LNG from Trains 5 and 6 of the Liquefaction Project and provide that cargoes rejected by Cheniere Marketing under the Base SPA can be sold by SPL to Cheniere Marketing at a contract price equal to a portion of the estimated net profits from the sale of such cargo. Cheniere Marketing Master SPA 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. Cheniere Marketing Letter Agreements In May 2022, SPL and Cheniere Marketing entered into a letter agreement for the sale of up to 32 TBtu of LNG to be delivered between 2023 and 2025 at a price of 115% of Henry Hub plus $3.00 per MMBtu. Cheniere Marketing has letter agreements with SPL to purchase up to 306 cargoes of LNG to be delivered between 2022 and 2027 at a weighted average price of $1.95 plus 115% of Henry Hub. SPL and Cheniere Marketing had a letter agreement for the sale of up to 30 cargoes of LNG that were delivered in 2021 at a price of 115% of Henry Hub plus $0.728 per MMBtu. Facility Swap Agreement SPL has an arrangement with subsidiaries of Cheniere to provide the ability, in limited circumstances, to potentially fulfill commitments to LNG buyers in the event operational conditions impact operations at either the Sabine Pass or Corpus Christi liquefaction facilities. The purchase price for such cargoes would be (1) 115% of the applicable natural gas feedstock purchase price or (2) a free-on-board U.S. Gulf Coast LNG market price, whichever is greater. Natural Gas Transportation and Storage Agreements SPL is party to various natural gas transportation and storage agreements and CTPL is party to an operational balancing agreement with a related party in the ordinary course of business for the operation of the Liquefaction Project, with initial primary terms of up to 10 years with extension rights. This related party is partially owned by Brookfield, who indirectly acquired a portion of our limited partner interests in September 2020 through its purchase of a portion of CQP Target Holdco’s equity interests. We recorded accrued liabilities—related party of $8 million and $4 million as of September 30, 2022 and December 31, 2021, respectively, with this related party. Services Agreements As of September 30, 2022 and December 31, 2021, we had $150 million and $141 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. CQP Services Agreement We have a services agreement with Cheniere Terminals 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 through 2042. 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 through 2029. 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) through 2029 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 necessary services required to operate and maintain the Liquefaction Project. After each Train of the Liquefaction Project 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 is required to 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 through 2042. 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 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 is required to pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, SPL is required to pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train through 2042. CTPL O&M Agreement CTPL has a 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. CTPL MSA CTPL has a management services agreement (the “CTPL MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the operations and business of the Creole Trail Pipeline, excluding those matters provided for under the CTPL O&M Agreement. The services include, among other services, exercising the day-to-day management of CTPL’s affairs and business, managing CTPL’s regulatory matters, managing bank and brokerage accounts and financial books and records of CTPL’s business and operations, providing contract administration services for all contracts associated with the Creole Trail Pipeline and obtaining insurance. CTPL is required to reimburse Cheniere Terminals for the aggregate of all costs and expenses incurred in the course of performing the services under the CTPL MSA. 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 advanced payments of annual ad valorem taxes from SPLNG from 2007 through 2016. This initiative represented an aggregate commitment of $25 million over 10 years 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 shall grant SPLNG a dollar-for-dollar credit against future ad valorem taxes to be levied against the Sabine Pass LNG Terminal as early as 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 the dollar-for-dollar credit applied to the ad valorem tax levied against the Sabine Pass LNG Terminal in the given year. 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 obligations. We had $3 million and $2 million in due to affiliates as of September 30, 2022 and December 31, 2021, respectively, and $15 million of other non-current liabilities—affiliate as of both September 30, 2022 and December 31, 2021, 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. SPL has an agreement with Corpus Christi Liquefaction, LLC (“CCL”) that allows them to sell and purchase natural gas from each other. Natural gas purchased under this agreement is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. Natural gas sold under this agreement is recorded as LNG revenues—affiliate. Terminal Marine Services Agreement In connection with its tug boat lease, Tug Services entered into an agreement with Cheniere Terminals 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 Cheniere Terminals a portion of its future revenues. Tug Services distributed $2 million during each of the three months ended September 30, 2022 and 2021 and $7 million and $6 million during the nine months ended September 30, 2022 and 2021, respectively, to Cheniere Terminals, which is recognized as part of the distributions to our general partner interest holders on our Consolidated Statements of Partners’ Equity (Deficit). 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 not record any revenues associated with this agreement during the three and nine months ended September 30, 2022 and 2021. State Tax Sharing Agreements SPLNG, SPL and CTPL each have a state tax sharing agreement with Cheniere. Under these agreements, Cheniere has agreed to prepare and file all state and local tax returns which each of the entities 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, each of the respective entities will pay to Cheniere an amount equal to the state and local tax that each of the entities would be required to pay if its state and local tax liability were calculated on a separate company basis. To date, there have been no state and local tax payments demanded by Cheniere under the tax sharing agreements. The agreements for SPLNG, SPL and CTPL are effective for tax returns due on or after January 2008, August 2012 and May 2013, respectively.

Net Income (Loss) per Common Un

Net Income (Loss) per Common Unit	9 Months Ended
	Sep. 30, 2022
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 common 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 Statements of Partners’ Equity (Deficit). On October 24, 2022, we declared a cash distribution of $1.070 per common unit to unitholders of record as of November 3, 2022 and the related general partner distribution to be paid on November 14, 2022. These distributions consist of a base amount of $0.775 per unit and a variable amount of $0.295 per unit. The two-class method dictates that net income 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 following table provides a reconciliation of net income (loss) and the allocation of net income (loss) 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). Total Limited Partner Common Units General Partner Units IDR Three Months Ended September 30, 2022 Net loss $ (514) Declared distributions 753 518 15 220 Assumed allocation of undistributed net loss (1) $ (1,267) (1,242) (25) — Assumed allocation of net loss $ (724) $ (10) $ 220 Weighted average units outstanding 484.0 Basic and diluted net loss per unit (2) $ (1.49) Three Months Ended September 30, 2021 Net income $ 381 Declared distributions 375 329 8 38 Assumed allocation of undistributed net income (1) $ 6 6 — — Assumed allocation of net income $ 335 $ 8 $ 38 Weighted average units outstanding 484.0 Basic and diluted net income per unit $ 0.69 Nine Months Ended September 30, 2022 Net loss $ (13) Declared distributions 2,229 1,539 45 645 Assumed allocation of undistributed net loss (1) $ (2,242) (2,197) (45) — Assumed allocation of net loss $ (658) $ — $ 645 Weighted average units outstanding 484.0 Basic and diluted net loss per unit $ (1.36) Nine Months Ended September 30, 2021 Net income $ 1,123 Declared distributions 1,091 970 22 99 Assumed allocation of undistributed net income (1) $ 32 31 1 — Assumed allocation of net income $ 1,001 $ 23 $ 99 Weighted average units outstanding 484.0 Basic and diluted net income per unit $ 2.07 (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) Basic and diluted net income (loss) 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, 2022
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2022 2021 2022 2021 2022 2021 Customer A 18% 20% 23% 24% 17% 28% Customer B 16% 19% 16% 17% * 17% Customer C 14% 18% 16% 18% * * Customer D 16% 17% 16% 16% 13% 14% Customer E * 11% * 11% * 12% Customer F 10% * * * * 12% Customer G 12% * * * 32% — * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2022
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, 2022 2021 Cash paid during the period for interest on debt, net of amounts capitalized $ 585 $ 601 The balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate) was $314 million and $233 million as of September 30, 2022 and 2021, respectively. Novation of IPM Agreement from Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”) In March 2022, in connection with a prior commitment from Cheniere to collateralize financing for Train 6 of the Liquefaction Project, SPL and CCL Stage III, formerly a wholly owned direct subsidiary of Cheniere that merged with and into CCL, entered into an agreement to assign to SPL an IPM agreement to purchase 140,000 MMBtu per day of natural gas at a price based on the Platts Japan Korea Marker (“JKM”), for a term of approximately 15 years beginning in early 2023. The transaction has been accounted for as a transfer between entities under common control, which required us to recognize the obligations assumed at the historical basis of Cheniere. Upon the transfer, which occurred on March 15, 2022, we recognized $2.7 billion in distributions to Cheniere’s common unitholder interest within our Consolidated Statements of Partners’ Equity (Deficit) based on our assumption of current derivative liabilities and derivative liabilities of $142 million and $2.6 billion, respectively, which represented a non-cash financing activity.

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Consolidated Financial Statements of CQP have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the financial results for the interim periods presented. 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 fiscal year ended December 31, 2021 . Results of operations for the three and nine months ended September 30, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022.
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.
Recent Accounting Standards	Recent Accounting Standards ASU 2020-04 In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting . This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The standard is effective from March 12, 2020 to December 31, 2022. We have not yet applied the optional expedients available under the standard because we have not yet modified any of our existing contracts indexed to LIBOR, mainly our credit facilities as further described in Note 9—Debt

Trade and Other Receivables, _2

Trade and Other Receivables, Net of Current Expected Credit Losses (Tables)	9 Months Ended
	Sep. 30, 2022
Receivables [Abstract]
Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses	Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2022 2021 Trade receivables $ 761 $ 546 Other receivables 44 34 Total trade and other receivables, net of current expected credit losses $ 805 $ 580

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consisted of the following (in millions): September 30, December 31, 2022 2021 Materials $ 100 $ 86 LNG 107 45 Natural gas 32 43 Other 2 2 Total inventory $ 241 $ 176

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2022 2021 LNG terminal Terminal and interconnecting pipeline facilities $ 19,459 $ 16,973 Construction-in-process 699 2,746 Accumulated depreciation (3,356) (2,893) Total LNG terminal, net of accumulated depreciation 16,802 16,826 Fixed assets Fixed assets 29 29 Accumulated depreciation (26) (25) Total fixed assets, net of accumulated depreciation 3 4 Assets under finance lease Tug vessels 23 — Accumulated depreciation (1) — Total assets under finance lease, net of accumulated depreciation 22 — Property, plant and equipment, net of accumulated depreciation $ 16,827 $ 16,830
Schedule of Depreciation and Offsets to LNG Terminal Costs	The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Depreciation expense $ 158 $ 139 $ 465 $ 414 Offsets to LNG terminal costs (1) — — 148 —

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Value of Derivative Assets and Liabilities	The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis (in millions): Fair Value Measurements as of September 30, 2022 December 31, 2021 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Liquefaction Supply Derivatives asset (liability) $ (30) $ (24) $ (5,024) $ (5,078) $ 2 $ (13) $ 38 $ 27
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, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(5,024) Market approach incorporating present value techniques Henry Hub basis spread $(2.495) - $0.677 / $(0.028) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 91% - 865% / 243% (1) Unobservable inputs were weighted by the relative fair value of the instruments. (2) Spread contemplates U.S. dollar-denominated pricing.
Fair Value, Liabilities 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 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Balance, beginning of period $ (3,456) $ 33 $ 38 $ (21) Realized and mark-to-market gains (losses): Included in cost of sales (1,545) 25 (155) 79 Purchases and settlements: Purchases (1) 3 4 (4,896) 6 Settlements (24) (3) (11) (5) Transfers out of Level 3, net (2) (2) — — — Balance, end of period $ (5,024) $ 59 $ (5,024) $ 59 Change in unrealized gains (losses) relating to instruments still held at end of period $ (1,545) $ 25 $ (155) $ 79 (1) Includes the assignment of an IPM agreement that occurred during the period, as discussed in Note 1 4 —Supplemental Cash Flow Information . (2) Transferred out of Level 3 as a result of unobservable market for the underlying natural gas purchase agreements.
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues $ (3) $ — $ 1 $ — Cost of sales (1,625) 10 (2,448) 64 (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.
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 Sheets Location September 30, 2022 December 31, 2021 Current derivative assets $ 27 $ 21 Derivative assets 33 33 Total derivative assets 60 54 Current derivative liabilities (1,157) (16) Derivative liabilities (3,981) (11) Total derivative liabilities (5,138) (27) Derivative asset (liability), net $ (5,078) $ 27 (1) Does not include collateral posted with counterparties by us of $59 million and $7 million, as of September 30, 2022 and December 31, 2021, respectively, which are included in other current assets in our Consolidated Balance Sheets.
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) for our derivative instruments that are presented on a net basis on our Consolidated Balance Sheets: Liquefaction Supply Derivatives As of September 30, 2022 Gross assets $ 67 Offsetting amounts (7) Net assets $ 60 Gross liabilities $ (5,158) Offsetting amounts 20 Net liabilities $ (5,138) As of December 31, 2021 Gross assets $ 79 Offsetting amounts (25) Net assets $ 54 Gross liabilities $ (33) Offsetting amounts 6 Net liabilities $ (27)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2022
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following (in millions): September 30, December 31, 2022 2021 Natural gas purchases $ 1,259 $ 786 Interest costs and related debt fees 201 180 LNG terminal and related pipeline costs 172 101 Other accrued liabilities 25 6 Total accrued liabilities $ 1,657 $ 1,073

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Schedule of Debt Instruments	Debt consisted of the following (in millions): September 30, December 31, 2022 2021 SPL: Senior Secured Notes: 5.625% due 2023 (the “2023 SPL Senior Notes”) (1) $ 1,500 $ 1,500 5.75% due 2024 2,000 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.27% weighted average rate due 2037 1,282 1,282 Total SPL Senior Secured Notes 13,132 13,132 Working capital revolving credit and letter of credit reimbursement agreement (the “SPL Working Capital Facility”) — — Total debt - SPL 13,132 13,132 CQP: Senior Notes: 4.500% due 2029 1,500 1,500 4.000% due 2031 1,500 1,500 3.25% due 2032 1,200 1,200 Total CQP Senior Notes 4,200 4,200 Credit facilities (the “CQP Credit Facilities”) — — Total debt - CQP 4,200 4,200 Total debt 17,332 17,332 Short-term debt (1,498) — Unamortized premium, discount and debt issuance costs, net (135) (155) Total long-term debt, net of premium, discount and debt issuance costs $ 15,699 $ 17,177 (1) In October 2022, $300 million of the 2023 SPL Senior Notes were redeemed. As of September 30, 2022, the entire amount of the 2023 SPL Senior Notes was classified as short-term debt.
Schedule of Line of Credit Facilities	Below is a summary of our credit facilities outstanding as of September 30, 2022 (in millions): SPL Working Capital Facility CQP Credit Facilities Total facility size $ 1,200 $ 750 Less: Outstanding balance — — Letters of credit issued 363 — Available commitment $ 837 $ 750 Priority ranking Senior secured Senior secured Interest rate on available balance LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125% Commitment fees on undrawn balance 0.15% 0.49% Maturity date March 19, 2025 May 29, 2024
Schedule of Interest Expense	Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Total interest cost $ 231 $ 244 $ 678 $ 732 Capitalized interest (9) (34) (37) (96) Total interest expense, net of capitalized interest $ 222 $ 210 $ 641 $ 636
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 16,050 $ 15,036 $ 16,050 $ 17,496 Senior notes — Level 3 (2) 1,282 1,119 1,282 1,466 (1) 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.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Revenues from contracts with customers LNG revenues $ 3,133 $ 1,791 $ 8,576 $ 5,057 LNG revenues—affiliate 1,376 453 3,268 878 LNG revenues—related party — — 4 — Regasification revenues 455 68 591 202 Other revenues 15 12 45 39 Total revenues from contracts with customers 4,979 2,324 12,484 6,176 Net derivative gain (loss) (1) (3) — 1 — Total revenues $ 4,976 $ 2,324 $ 12,485 $ 6,176 (1) See Note 7—Derivative Instruments for additional information about our derivatives.
Contract with Customer, Asset	The following table shows our contract assets, net of current expected credit losses, which are classified as contract assets and other non-current assets, net on our Consolidated Balance Sheets (in millions): September 30, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 388 $ 1
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue, beginning of period $ 155 Cash received but not yet recognized in revenue 162 Revenue recognized from prior period deferral (155) Deferred revenue, end of period $ 162 The following table reflects the changes in our contract liabilities to affiliate, which we classify as deferred revenue—affiliate and other non-current liabilities—affiliate on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue—affiliate, beginning of period $ 3 Cash received but not yet recognized in revenue 6 Revenue recognized from prior year end deferral (3) Deferred revenue—affiliate, end of period $ 6
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: September 30, 2022 December 31, 2021 Unsatisfied Weighted Average Recognition Timing (years) (1) Unsatisfied Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.6 8 $ 49.3 9 LNG revenues—affiliate 2.0 2 2.1 3 Regasification revenues 1.6 2 1.9 4 Total revenues $ 55.2 $ 53.3 (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, 2022
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 Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 1,328 $ 441 $ 3,173 $ 860 Contracts for Sale and Purchase of Natural Gas and LNG 48 12 95 18 Total LNG revenues—affiliate 1,376 453 3,268 878 LNG revenues—related party Natural Gas Transportation and Storage Agreements — — 4 — Cost of sales—affiliate Cheniere Marketing Agreements — — — 34 Contracts for Sale and Purchase of Natural Gas and LNG 104 8 166 28 Total cost of sales—affiliate 104 8 166 62 Cost of sales—related party Natural Gas Transportation and Storage Agreements — — 1 1 Operating and maintenance expense—affiliate Services Agreements 39 34 118 103 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 18 12 45 34 General and administrative expense—affiliate Services Agreements 23 22 70 64

Net Income (Loss) per Common _2

Net Income (Loss) per Common Unit (Tables)	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Schedule of Net Income (Loss) per Common Unit	The following table provides a reconciliation of net income (loss) and the allocation of net income (loss) 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). Total Limited Partner Common Units General Partner Units IDR Three Months Ended September 30, 2022 Net loss $ (514) Declared distributions 753 518 15 220 Assumed allocation of undistributed net loss (1) $ (1,267) (1,242) (25) — Assumed allocation of net loss $ (724) $ (10) $ 220 Weighted average units outstanding 484.0 Basic and diluted net loss per unit (2) $ (1.49) Three Months Ended September 30, 2021 Net income $ 381 Declared distributions 375 329 8 38 Assumed allocation of undistributed net income (1) $ 6 6 — — Assumed allocation of net income $ 335 $ 8 $ 38 Weighted average units outstanding 484.0 Basic and diluted net income per unit $ 0.69 Nine Months Ended September 30, 2022 Net loss $ (13) Declared distributions 2,229 1,539 45 645 Assumed allocation of undistributed net loss (1) $ (2,242) (2,197) (45) — Assumed allocation of net loss $ (658) $ — $ 645 Weighted average units outstanding 484.0 Basic and diluted net loss per unit $ (1.36) Nine Months Ended September 30, 2021 Net income $ 1,123 Declared distributions 1,091 970 22 99 Assumed allocation of undistributed net income (1) $ 32 31 1 — Assumed allocation of net income $ 1,001 $ 23 $ 99 Weighted average units outstanding 484.0 Basic and diluted net income per unit $ 2.07 (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) Basic and diluted net income (loss) 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, 2022
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2022 2021 2022 2021 2022 2021 Customer A 18% 20% 23% 24% 17% 28% Customer B 16% 19% 16% 17% * 17% Customer C 14% 18% 16% 18% * * Customer D 16% 17% 16% 16% 13% 14% Customer E * 11% * 11% * 12% Customer F 10% * * * * 12% Customer G 12% * * * 32% — * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2022
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, 2022 2021 Cash paid during the period for interest on debt, net of amounts capitalized $ 585 $ 601

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details) shares in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2022 item unit milliontonnes / yr mi trains shares	Dec. 31, 2021
Cheniere Partners [Member]
Nature of Operations and Basis of Presentation [Line Items]
General Partner Ownership Interest Percentage	2%	2%
Cheniere Partners [Member] | Cheniere [Member]
Nature of Operations and Basis of Presentation [Line Items]
Limited Partner Ownership Percentage	48.60%
General Partner Ownership Interest Percentage	100%
Cheniere Partners [Member] | Cheniere [Member] | Common Units [Member]
Nature of Operations and Basis of Presentation [Line Items]
Partners' Capital Account, Units, Units Held | shares	239.9
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating | trains	6
Total Production Capability | milliontonnes / yr	30
Number Of LNG Storage Tanks | unit	5
Number of Marine Berths Operating | item	3
Creole Trail Pipeline [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	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Maximum [Member]
Other Ownership Interests [Line Items]
Number of days after quarter end distribution is paid	45 days
General Partner [Member] | Minimum [Member]
Other Ownership Interests [Line Items]
Distributions entitled by General Partner, Percentage	2%
Incentive Distribution, Quarterly Distribution Additional Target Percentage	15%
General Partner [Member] | Maximum [Member]
Other Ownership Interests [Line Items]
Incentive Distribution, Quarterly Distribution Additional Target Percentage	50%
Cheniere Partners [Member]
Other Ownership Interests [Line Items]
General Partner Ownership Interest Percentage	2%	2%
Cheniere [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	48.60%
General Partner Ownership Interest Percentage	100%
CQP Target Holdco LLC and Other Blackstone and Brookfield Affiliates [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	41.40%
Public [Member] | Cheniere Partners [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	8%
BIP Chinook Holdco LLC [Member] | CQP Target Holdco LLC [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	50%
BIF IV Cypress Aggregator (Delaware) LLC [Member] | CQP Target Holdco LLC [Member]
Other Ownership Interests [Line Items]
Limited Partner Ownership Percentage	50%

Restricted Cash and Cash Equi_2

Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 195	$ 98
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 195	$ 98

Trade and Other Receivables, _3

Trade and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Receivables [Abstract]
SPL trade receivable	$ 761	$ 546
Other receivables	44	34
Total trade and other receivables, net of current expected credit losses	$ 805	$ 580

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Inventory [Line Items]
Inventory	$ 241	$ 176
Materials [Member]
Inventory [Line Items]
Inventory	100	86
LNG [Member]
Inventory [Line Items]
Inventory	107	45
Natural gas [Member]
Inventory [Line Items]
Inventory	32	43
Other [Member]
Inventory [Line Items]
Inventory	$ 2	$ 2

Property, Plant and Equipment_3

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Property, Plant and Equipment, Net of Accumulated Depreciation (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 16,827	$ 16,830
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(3,356)	(2,893)
Property, plant and equipment, net of accumulated depreciation	16,802	16,826
LNG terminal and interconnecting pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	19,459	16,973
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	699	2,746
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	29	29
Accumulated depreciation	(26)	(25)
Property, plant and equipment, net of accumulated depreciation	3	4
Assets Held under Capital Leases
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	23	0
Accumulated depreciation	(1)	0
Property, plant and equipment, net of accumulated depreciation	$ 22	$ 0

Property, Plant and Equipment_4

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Depreciation and Offsets to LNG Terminal Costs (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 158	$ 139	$ 465	$ 414
Offsets to LNG terminal costs	[1]	$ 0	$ 0	$ 148	$ 0
[1]We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Project during the testing phase for its construction.

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - SPL [Member] - tbtu	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	5,220	5,194
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	15 years
Financial Liquefaction Supply Derivatives | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	3 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (5,078)	$ 27
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	(30)	2
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	(24)	(13)
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	$ (5,024)	$ 38

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - USD ($)		9 Months Ended
		Sep. 30, 2022	Dec. 31, 2021
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liability		$ (5,078,000,000)	$ 27,000,000
Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liability		(5,024,000,000)	$ 38,000,000
Physical Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liability		(5,024,000,000)
Physical Liquefaction Supply Derivatives [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Input Range	[1]	$ (2.495)
Physical Liquefaction Supply Derivatives [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	91%
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Input Range	[1]	$ 0.677
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	865%
Physical Liquefaction Supply Derivatives [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Input Range	[1]	$ (0.028)
Physical Liquefaction Supply Derivatives [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	243%
[1]Unobservable inputs were weighted by the relative fair value of the instruments.[2]Spread contemplates U.S. dollar-denominated pricing.

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, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ (3,456)	$ 33	$ 38	$ (21)
Realized and mark-to-market gains (losses):
Included in cost of sales		(1,545)	25	(155)	79
Purchases and settlements:
Purchases	[1]	3	4	(4,896)	6
Settlements		(24)	(3)	(11)	(5)
Transfers out of Level 3, net	[2]	(2)	0	0	0
Balance, end of period		(5,024)	59	(5,024)	59
Change in unrealized gains (losses) relating to instruments still held at end of period		$ (1,545)	$ 25	$ (155)	$ 79
[1] Includes the assignment of an IPM agreement that occurred during the period, as discussed in Note 1 4 —Supplemental Cash Flow Information .

Derivative Instruments - Deriva

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
LNG revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ (3)	$ 0	$ 1	$ 0
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ (1,625)	$ 10	$ (2,448)	$ 64
[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 - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 27	$ 21
Derivative assets		33	33
Total derivative assets	[1]	60	54
Current derivative liabilities		(1,157)	(16)
Derivative liabilities		(3,981)	(11)
Total derivative liabilities	[1]	(5,138)	(27)
Derivative asset (liability), net	[1]	(5,078)	27
Derivative, collateral posted by us		59	7
Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	27	21
Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	33	33
Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(1,157)	(16)
Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	$ (3,981)	$ (11)
[1]Does not include collateral posted with counterparties by us of $59 million and $7 million, as of September 30, 2022 and December 31, 2021, respectively, which are included in other current assets in our Consolidated Balance Sheets.

Derivative Instruments - Balanc

Derivative Instruments - Balance Sheet Presentation Table (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (5,078)	$ 27
Liquefaction Supply Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	67	79
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheet	(7)	(25)
Derivative Assets (Liabilities), at Fair Value, Net	60	54
Liquefaction Supply Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(5,158)	(33)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheet	20	6
Derivative Assets (Liabilities), at Fair Value, Net	$ (5,138)	$ (27)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Accrued Liabilities, Current [Abstract]
Natural gas purchases	$ 1,259	$ 786
Interest costs and related debt fees	201	180
LNG terminal and related pipeline costs	172	101
Other accrued liabilities	25	6
Total accrued liabilities	$ 1,657	$ 1,073

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		Oct. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 17,332	$ 17,332
Current debt, net of discount and debt issuance costs			(1,498)	0
Unamortized premium, discount and debt issuance costs, net			(135)	(155)
Long-term Debt, Net of Premium, Discount and Debt Issuance Costs			15,699	17,177
SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			13,132	13,132
2023 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1]		$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage			5.625%
2023 SPL Senior Notes [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt		$ 300
2024 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage			5.75%
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage			5.625%
2026 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage			5.875%
2027 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage			5%
2028 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,350	1,350
Debt Instrument, Interest Rate, Stated Percentage			4.20%
2030 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage			4.50%
2037 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,282	1,282
2037 SPL Senior Notes [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.27%
SPL Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 0	0
CQP Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			4,200	4,200
2029 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage			4.50%
2031 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage			4%
2032 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 1,200	1,200
Debt Instrument, Interest Rate, Stated Percentage			3.25%
CQP Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 0	0
SPL [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			13,132	13,132
Cheniere Partners [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 4,200	$ 4,200
[1]In October 2022, $300 million of the 2023 SPL Senior Notes were redeemed. As of September 30, 2022, the entire amount of the 2023 SPL Senior Notes was classified as short-term debt.

Debt - Credit Facilities Table

Debt - Credit Facilities Table (Details) $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) unit Rate	Dec. 31, 2021 USD ($)
Line of Credit Facility [Line Items]
Outstanding balance	$ 17,332	$ 17,332
Debt, Minimum Historical Debt Service Coverage Ratio And Projected Debt Service Coverage Ratio | unit	1.25
SPL Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Total facility size	$ 1,200
Outstanding balance	0	0
Letters of credit issued	363
Available commitment	$ 837
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Line of Credit Facility, Commitment Fee Percentage	0.15%
Debt Instrument, Maturity Date	Mar. 19, 2025
SPL Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.125%
SPL Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.75%
SPL Working Capital Facility [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.125%
SPL Working Capital Facility [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.75%
CQP Credit Facilities [Member]
Line of Credit Facility [Line Items]
Total facility size	$ 750
Outstanding balance	0	$ 0
Letters of credit issued	0
Available commitment	$ 750
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Line of Credit Facility, Commitment Fee Percentage	0.49%
Debt Instrument, Maturity Date	May 29, 2024
CQP Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.25%
CQP Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	2.125%
CQP Credit Facilities [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.25%
CQP Credit Facilities [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.125%

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Debt Disclosure [Abstract]
Total interest cost	$ 231	$ 244	$ 678	$ 732
Capitalized interest	(9)	(34)	(37)	(96)
Total interest expense, net of capitalized interest	$ 222	$ 210	$ 641	$ 636

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - Senior Notes [Member] - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[1]	$ 16,050	$ 16,050
Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[2]	1,282	1,282
Estimated Fair Value [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	15,036	17,496
Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	$ 1,119	$ 1,466
[1]The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.[2]The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.

Revenues - Schedule of Disaggre

Revenues - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 4,979	$ 2,324	$ 12,484	$ 6,176
Net derivative gain (loss)	[1]	(3)	0	1	0
Total revenues		4,976	2,324	12,485	6,176
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		3,133	1,791	8,576	5,057
Total revenues		3,130	1,791	8,577	5,057
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		1,376	453	3,268	878
LNG—related party[Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	0	4	0
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		455	68	591	202
Other [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 15	$ 12	$ 45	$ 39
[1] See Note 7—Derivative Instruments for additional information about our derivatives.

Revenues - Contract Assets and

Revenues - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 388	$ 1
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenues, beginning of period	155
Cash received but not yet recognized in revenue	162
Revenue recognized from prior period deferral	(155)
Deferred revenues, end of period	162
Deferred revenue—affiliate, beginning of period	3
Cash received but not yet recognized in revenue	6
Revenue recognized from prior year end deferral	(3)
Deferred revenue—affiliate, end of period	$ 6

Revenues - Schedule of Transact

Revenues - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 53.3
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 55.2		$ 55.2
LNG [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		78%	63%	74%	56%
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 49.3
Weighted Average Recognition Timing	[1]					9 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 51.6		$ 51.6
Weighted Average Recognition Timing	[1]	8 years		8 years
LNG—affiliate [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		77%	96%	76%	94%
LNG—affiliate [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 2.1
Weighted Average Recognition Timing	[1]					3 years
LNG—affiliate [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 2		$ 2
Weighted Average Recognition Timing	[1]	2 years		2 years
Regasification [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		1%	5%	2%	5%
Regasification [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 1.9
Weighted Average Recognition Timing	[1]					4 years
Regasification [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 1.6		$ 1.6
Weighted Average Recognition Timing	[1]	2 years		2 years
[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.

Revenues - Termination Agreemen

Revenues - Termination Agreement with Chevron (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Sep. 30, 2022	Dec. 31, 2021
Revenue from External Customer [Line Items]
Contract assets		$ 387	$ 0
Chevron U.S.A. Inc.
Revenue from External Customer [Line Items]
Contract Termination Fee	$ 765
Chevron U.S.A. Inc. | Terminated commitments [Member]
Revenue from External Customer [Line Items]
Contract Termination Fee	796
Chevron U.S.A. Inc. | Gain (Loss) on extinguishment of obligations [Member]
Revenue from External Customer [Line Items]
Contract Termination Fee	(31)
Chevron U.S.A. Inc. | Regasification [Member]
Revenue from External Customer [Line Items]
Revenue, Performance Obligation, Fixed Consideration	$ 125
Contract assets		$ 387

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Related Party Transaction [Line Items]
Cost of sales—affiliate	$ 104	$ 8	$ 166	$ 62
Cost of sales—related party	0	0	1	1
Operating and maintenance expense—affiliate	39	34	118	103
Operating and maintenance expense—related party	18	12	45	34
General and administrative expense—affiliate	23	22	70	64
Revenues from contracts with customers	4,979	2,324	12,484	6,176
LNG—affiliate [Member]
Related Party Transaction [Line Items]
Revenues from contracts with customers	1,376	453	3,268	878
LNG—related party[Member]
Related Party Transaction [Line Items]
Revenues from contracts with customers	0	0	4	0
Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	0	0	0	34
Cheniere Marketing Agreements [Member] | LNG—affiliate [Member]
Related Party Transaction [Line Items]
Revenues from contracts with customers	1,328	441	3,173	860
Contracts for Sale and Purchase of Natural Gas And LNG [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	104	8	166	28
Contracts for Sale and Purchase of Natural Gas And LNG [Member] | LNG—affiliate [Member]
Related Party Transaction [Line Items]
Revenues from contracts with customers	48	12	95	18
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Cost of sales—related party	0	0	1	1
Operating and maintenance expense—related party	18	12	45	34
Natural Gas Transportation and Storage Agreements [Member] | LNG—related party[Member]
Related Party Transaction [Line Items]
Revenues from contracts with customers	0	0	4	0
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	39	34	118	103
General and administrative expense—affiliate	$ 23	$ 22	$ 70	$ 64

Related Party Transactions - Ch

Related Party Transactions - Cheniere Marketing Agreements (Details) - SPL [Member]	9 Months Ended
	Sep. 30, 2022 USD ($) tbtu Cargo
Affiliated Entity [Member] | Facility Swap Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
Cheniere Marketing [Member] | Cheniere Marketing SPA [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
LNG Volume, Purchase Price Per MMBtu	$ 3
Cheniere Marketing [Member] | 2022 Letter Agreement
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
LNG Volume, Purchase Price Per MMBtu	$ 3
Cheniere Marketing [Member] | 2022 Letter Agreement | Maximum [Member]
Related Party Transaction [Line Items]
Contract Volume | tbtu	32
Cheniere Marketing [Member] | 2022 - 2027 Letter Agreements
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
LNG Volume, Weighted Average Purchase Price Per MMBtu	$ 1.95
Cheniere Marketing [Member] | 2022 - 2027 Letter Agreements | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	306
Cheniere Marketing [Member] | 2021 Letter Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
LNG Volume, Purchase Price Per MMBtu	$ 0.728
Cheniere Marketing [Member] | 2021 Letter Agreement [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	30

Related Party Transactions - Se

Related Party Transactions - Service Agreements (Details) - USD ($)	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Advances to Affiliate Current	$ 150,000,000	$ 141,000,000
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to Affiliate Current	150,000,000	$ 141,000,000
Cheniere Terminals [Member] | Cheniere Partners Services Agreement [Member]
Related Party Transaction [Line Items]
Quarterly non-accountable overhead reimbursement charge	$ 3,000,000
SPL [Member] | Cheniere Terminals [Member] | Management Services Agreement [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
SPL [Member] | Cheniere Investments [Member] | Operation and Maintenance Agreement [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
SPLNG [Member] | Cheniere Terminals [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	520,000
SPLNG [Member] | Cheniere Investments [Member] | Operation and Maintenance Agreement [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%

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Related Party Transaction [Line Items]
Accounts receivable—affiliate	$ 447,000,000		$ 447,000,000		$ 232,000,000
Accrued liabilities—related party	8,000,000		8,000,000		4,000,000
Due to affiliates	56,000,000		56,000,000		67,000,000
Other non-current liabilities—affiliate	21,000,000		21,000,000		18,000,000
SPLNG [Member] | Cooperative Endeavor Agreements [Member]
Related Party Transaction [Line Items]
Aggregate commitment under the Agreement	25,000,000		$ 25,000,000
Tax Initiative Agreement Term			10 years
SPLNG [Member] | Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			$ 0
SPLNG [Member] | Cheniere Marketing [Member] | Cooperative Endeavor Agreements [Member]
Related Party Transaction [Line Items]
Due to affiliates	3,000,000		3,000,000		2,000,000
Other non-current liabilities—affiliate	15,000,000		15,000,000		15,000,000
SPLNG [Member] | Cheniere Marketing [Member] | LNG Terminal Export Agreement [Member]
Related Party Transaction [Line Items]
LNG revenues—related party	0	$ 0	0	$ 0
Tug Services [Member] | Cheniere Terminals [Member] | Terminal Marine Services Agreement [Member]
Related Party Transaction [Line Items]
General Partner Distributions	2,000,000	$ 2,000,000	$ 7,000,000	$ 6,000,000
SPL and CTPL [Member] | Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term			10 years
Accrued liabilities—related party	$ 8,000,000		$ 8,000,000		$ 4,000,000
SPL [Member] | Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			0
CTPL [Member] | Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net			$ 0

Net Income (Loss) per Common _3

Net Income (Loss) per Common Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions			3 Months Ended							9 Months Ended
		Oct. 24, 2022	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss)			$ (514)		$ 342	$ 159	$ 381	$ 395	$ 347	$ (13)	$ 1,123
Declared distributions			753				375			2,229	1,091
Assumed allocation of undistributed net income (loss)	[1]		$ (1,267)				$ 6			$ (2,242)	$ 32
Weighted average units outstanding			484				484			484	484
Basic and diluted net income per unit			$ (1.49)				$ 0.69			$ (1.36)	$ 2.07
Common Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss)			$ (503)		335	157	$ 373	387	340
Declared distributions			518				329			$ 1,539	$ 970
Assumed allocation of undistributed net income (loss)	[1]		(1,242)				6			(2,197)	31
Assumed allocation of net income			$ (724)				$ 335			$ (658)	$ 1,001
Weighted average units outstanding			484				484			484	484
Basic and diluted net income per unit			$ (1.49)	[2]			$ 0.69			$ (1.36)	$ 2.07
Common Units [Member] | Subsequent Event [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 1.070
Common Units [Member] | Subsequent Event [Member] | Base Amount
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		0.775
Common Units [Member] | Subsequent Event [Member] | Variable Amount
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.295
General Partner [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss)			$ (11)		$ 7	$ 2	$ 8	$ 8	$ 7
Declared distributions			15				8			$ 45	$ 22
Assumed allocation of undistributed net income (loss)	[1]		(25)				0			(45)	1
Assumed allocation of net income			(10)				8			0	23
IDR [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Declared distributions			220				38			645	99
Assumed allocation of undistributed net income (loss)	[1]		0				0			0	0
Assumed allocation of net income			$ 220				$ 38			$ 645	$ 99
[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]Basic and diluted net income (loss) 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 - Schedu

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	18%	20%	23%	24%
Customer A [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			17%		28%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	16%	19%	16%	17%
Customer B [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					17%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	14%	18%	16%	18%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	16%	17%	16%	16%
Customer D [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			13%		14%
Customer E [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage		11%		11%
Customer E [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					12%
Customer F [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	10%
Customer F [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					12%
Customer G | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12%
Customer G | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			32%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) $ in Millions		6 Months Ended	9 Months Ended
	Mar. 15, 2022 USD ($)	Jun. 30, 2022 MMBTU	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized			$ 585	$ 601
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate)			314	$ 233
Nonmonetary Transaction [Line Items]
Novation of IPM agreement from Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”)	$ (2,700)
Current derivative liabilities			1,157		$ 16
Derivative liabilities			$ 3,981		$ 11
Novation of IPM Agreement [Member] | Cheniere Corpus Christi Liquefaction Stage III
Nonmonetary Transaction [Line Items]
Contract Volume | MMBTU		140,000
IPM Agreement, Term of Agreement		15 years
Current derivative liabilities	142
Derivative liabilities	$ 2,600