cqp-20240630

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2024

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 001-33366

Cheniere Energy Partners, L.P.

(Exact name of registrant as specified in its charter)


Delaware			20-5913059
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

845 Texas Avenue, Suite 1250

Houston, Texas 77002

(Address of principal executive offices) (Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Units Representing Limited Partner Interests	CQP	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of August 2, 2024, the registrant had 484,043,623 common units outstanding.

CHENIERE ENERGY PARTNERS, L.P.

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	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Statements of Operations	3
	Consolidated Balance Sheets	4
	Consolidated Statements of Partners’ Deficit	5
	Consolidated Statements of Cash Flows	6
	Notes to Consolidated Financial Statements	7
	Note 1—Nature of Operations and Basis of Presentation	7
	Note 2—Unitholders’ Equity	7

	Note 3—Trade and Other Receivables, Net of Current Expected Credit Losses	8
	Note 4—Inventory	8
	Note 5—Property, Plant and Equipment, Net of Accumulated Depreciation	9
	Note 6—Derivative Instruments	9

	Note 7—Accrued Liabilities	12
	Note 8—Debt	13
	Note 9—Revenues	14
	Note 10—Related Party Transactions	16
	Note 11—Net Income per Common Unit	17
	Note 12—Customer Concentration	19
	Note 13—Supplemental Cash Flow Information	19

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	20

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	29

Item 4.	Controls and Procedures	29

Part II. Other Information
Item 1.	Legal Proceedings	31

Item 1A.	Risk Factors	31

Item 5.	Other Information	31

Item 6.	Exhibits	31

	Signatures	32

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DEFINITIONS

As used in this quarterly report, the terms listed below have the following meanings:

Common Industry and Other Terms


ASU						Accounting Standards Update

Bcf/d						billion cubic feet per day

Bcfe						billion cubic feet equivalent

DOE						U.S. Department of Energy
EPC						engineering, procurement and construction
ESG						environmental, social and governance
FASB						Financial Accounting Standards Board
FERC						Federal Energy Regulatory Commission
FID						final investment decision

FTA countries						countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAP						generally accepted accounting principles in the United States
Henry Hub						the final settlement price (in U.S. dollars per MMBtu) for the New York Mercantile Exchange’s Henry Hub natural gas futures contract for the month in which a relevant cargo’s delivery window is scheduled to begin
IPM agreements						integrated production marketing agreements in which the gas producer sells to us gas on a global LNG or natural gas index price, less a fixed liquefaction fee, shipping and other costs

LNG						liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state
MMBtu						million British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
mtpa						million tonnes per annum
non-FTA countries						countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC						U.S. Securities and Exchange Commission
SOFR						Secured Overnight Financing Rate
SPA						LNG sale and purchase agreement
TBtu						trillion British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
Train						an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA						terminal use agreement

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Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of June 30, 2024, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:

Unless the context requires otherwise, references to “CQP,” the “Partnership,” “we,” “us” and “our” refer to Cheniere Energy Partners, L.P. and its consolidated subsidiaries.

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PART I. FINANCIAL INFORMATION

ITEM I. CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per unit data)

(unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Revenues
LNG revenues	$	1,454	$	1,415	$	3,174	$	3,521
LNG revenues—affiliate	391		469		915		1,230

Regasification revenues	34		33		68		67

Other revenues	15		16		32		32

Total revenues	1,894		1,933		4,189		4,850

Operating costs and expenses
Cost of sales (excluding items shown separately below)	661		603		1,625		916
Cost of sales—affiliate	—		1		4		18

Operating and maintenance expense	210		263		410		469
Operating and maintenance expense—affiliate	39		38		82		82
Operating and maintenance expense—related party	16		14		29		30


General and administrative expense	3		3		6		6
General and administrative expense—affiliate	23		24		45		46
Depreciation and amortization expense	170		167		338		334
Other operating costs and expenses	5		2		8		2
Other operating costs and expenses—affiliate	1		—		1		—
Total operating costs and expenses	1,128		1,115		2,548		1,903

Income from operations	766		818		1,641		2,947

Other income (expense)
Interest expense, net of capitalized interest	(202)		(207)		(404)		(415)
Loss on modification or extinguishment of debt	(3)		(2)		(3)		(2)
Interest and dividend income	9		13		18		27


Total other expense	(196)		(196)		(389)		(390)

Net income	$	570	$	622	$	1,252	$	2,557

Basic and diluted net income per common unit (1)	$	0.95	$	0.84	$	2.13	$	4.35


Weighted average basic and diluted number of common units outstanding	484.0		484.0		484.0		484.0

(1)In computing basic and diluted net income per common unit, net income is reduced by the amount of undistributed net income allocated to participating securities other than common units, as required under the two-class method. See Note 11—Net Income per Common Unit.

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in millions, except unit data)


	June 30,		December 31,

	2024		2023
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	351	$	575
Restricted cash and cash equivalents	68		56
Trade and other receivables, net of current expected credit losses	286		373
Trade receivables—affiliate	144		278

Advances to affiliate	122		84
Inventory	144		142
Current derivative assets	18		30


Other current assets, net	94		43
Other current assets—affiliate	1		—
Total current assets	1,228		1,581


Property, plant and equipment, net of accumulated depreciation	15,995		16,212
Operating lease assets	80		81

Derivative assets	26		40
Other non-current assets, net	186		188

Total assets	$	17,515	$	18,102

LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities
Accounts payable	$	51	$	69
Accrued liabilities	673		806
Accrued liabilities—related party	4		5
Current debt, net of unamortized debt issuance costs	798		300
Due to affiliates	37		55
Deferred revenue	78		114
Deferred revenue—affiliate	—		3

Current derivative liabilities	235		196
Other current liabilities	10		18
Total current liabilities	1,886		1,566

Long-term debt, net of unamortized discount and debt issuance costs	14,803		15,606

Operating lease liabilities	78		71
Finance lease liabilities	70		14
Derivative liabilities	1,319		1,531
Other non-current liabilities	93		75
Other non-current liabilities—affiliate	22		23
Total liabilities	18,271		18,886



Partners’ deficit
Common unitholders’ interest (484.0 million units issued and outstanding at both June 30, 2024 and December 31, 2023)	1,372		1,038
General partner’s interest (2% interest with 9.9 million units issued and outstanding at both June 30, 2024 and December 31, 2023)	(2,128)		(1,822)
Total partners’ deficit	(756)		(784)
Total liabilities and partners’ deficit	$	17,515	$	18,102

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF PARTNERS’ DEFICIT

(in millions)

(unaudited)


Three and Six Months Ended June 30, 2024
	Common Unitholders’ Interest			General Partner’s Interest			Total Partners’ Deficit
	Units	Amount		Units	Amount
















Balance at December 31, 2023	484.0	$	1,038	9.9	$	(1,822)	$	(784)
Net income	—	668		—	14		682

Distributions
Common units, $1.035/unit	—	(501)		—	—		(501)

General partner units	—	—		—	(219)		(219)
Balance at March 31, 2024	484.0	1,205		9.9	(2,027)		(822)





Net income	—	559		—	11		570
Distributions
Common units, $0.810/unit	—	(392)		—	—		(392)
General partner units	—	—		—	(112)		(112)

Balance at June 30, 2024	484.0	$	1,372	9.9	$	(2,128)	$	(756)


Three and Six Months Ended June 30, 2023
	Common Unitholders’ Interest			General Partner’s Interest	Total Partners’ Deficit
	Units	Amount				Units			Amount
Balance at December 31, 2022	484.0	$	(1,118)		9.9		$	(1,013)		$	(2,131)
Net income	—	1,897			—		38			1,935

Distributions
Common units, $1.070/unit	—	(518)			—		—			(518)
General partner units	—	—			—		(236)			(236)
Balance at March 31, 2023	484.0	261			9.9		(1,211)			(950)
Net income	—	610			—		12			622
Distributions
Common units, $1.03/unit	—	(499)			—		—			(499)
General partner units	—	—			—		(219)			(219)
Balance at June 30, 2023	484.0	$	372		9.9		$	(1,418)		$	(1,046)

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)


	Six Months Ended June 30,
	2024		2023
Cash flows from operating activities
Net income	$	1,252	$	2,557
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	338		334
Amortization of discount and debt issuance costs	13		15
Loss on modification or extinguishment of debt	3		2
Total gains on derivative instruments, net	(164)		(1,502)

Net cash provided by settlement of derivative instruments	17		2

Other	9		11

Changes in operating assets and liabilities:
Trade and other receivables	88		450
Trade receivables—affiliate	134		417

Advances to affiliate	(38)		21
Inventory	(3)		30


Accounts payable and accrued liabilities	(146)		(739)
Accrued liabilities—related party	—		(2)
Due to affiliates	(18)		(34)
Total deferred revenue	(19)		(21)
Other, net	(62)		1
Other, net—affiliate	(3)		(4)
Net cash provided by operating activities	1,401		1,538

Cash flows from investing activities
Property, plant and equipment, net	(66)		(149)
Other	(3)		(6)
Net cash used in investing activities	(69)		(155)

Cash flows from financing activities
Proceeds from issuances of debt	1,228		1,397
Repayments of debt	(1,530)		(200)
Debt issuance and other financing costs	(15)		(27)


Distributions	(1,224)		(1,472)
Other	(3)		(2)
Net cash used in financing activities	(1,544)		(304)

Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents	(212)		1,079
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	631		996
Cash, cash equivalents and restricted cash and cash equivalents—end of period	$	419	$	2,075

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We own a natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal”) which has six operational Trains, 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. Additionally, the Sabine Pass LNG Terminal includes a 94-mile natural gas supply pipeline that interconnects the Sabine Pass LNG Terminal with several large interstate and intrastate pipelines (the “Creole Trail Pipeline”).

We are pursuing an expansion project to provide additional liquefaction capacity, and we have commenced commercialization to support the additional liquefaction capacity associated with this potential expansion project. 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 FID.

We do not have employees and thus we and our subsidiaries have various services agreements with affiliates of Cheniere in the ordinary course of business, including services required to construct, operate and maintain the Liquefaction Project, and administrative services. See Note 10—Related Party Transactions for additional details of the activity under these services agreements during the three and six months ended June 30, 2024 and 2023.

As of June 30, 2024, 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, 2023.

Results of operations for the three and six months ended June 30, 2024 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2024.

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 2023-07

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280). This guidance requires a public entity, including entities with a single reportable segment, to disclose significant segment expenses and other segment items on an annual and interim basis and provide in interim periods all disclosures about a reportable segment’s profit or loss and assets that are currently required annually. We plan to adopt this guidance and conform with the applicable disclosures retrospectively when it becomes mandatorily effective for our annual report for the year ending December 31, 2024.

NOTE 2—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.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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, which, as defined in our partnership agreement, is generally 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 June 30, 2024, our total securities beneficially owned in the form of common units were held 48.6% by Cheniere, 41.5% by CQP Target Holdco L.L.C. (“CQP Target Holdco”) and other affiliates of Blackstone Inc. (“Blackstone”) and Brookfield Asset Management Inc. (“Brookfield”) and 7.9% 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.

NOTE 3—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):


	June 30,		December 31,

	2024		2023
Trade receivables	$	276	$	364
Other receivables	10		9
Total trade and other receivables, net of current expected credit losses	$	286	$	373

NOTE 4—INVENTORY

Inventory consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Materials	$	111	$	107
Natural gas	19		22
LNG	12		12
Other	2		1
Total inventory	$	144	$	142

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 5—PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION

Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
LNG terminal
Terminal and interconnecting pipeline facilities	$	20,231	$	20,176

Construction-in-process	191		189
Accumulated depreciation	(4,506)		(4,173)
Total LNG terminal, net of accumulated depreciation	15,916		16,192
Fixed assets
Fixed assets	32		29
Accumulated depreciation	(26)		(26)
Total fixed assets, net of accumulated depreciation	6		3
Assets under finance leases
Tug vessels	74		23
Accumulated depreciation	(1)		(6)
Total assets under finance leases, net of accumulated depreciation	73		17
Property, plant and equipment, net of accumulated depreciation	$	15,995	$	16,212

Depreciation expense was $169 million and $166 million during the three months ended June 30, 2024 and 2023, respectively, and $336 million and $331 million during the six months ended June 30, 2024 and 2023, respectively.

NOTE 6—DERIVATIVE INSTRUMENTS

We have commodity derivatives consisting of natural gas supply contracts, including those under our IPM agreements, for the operation of the Liquefaction Project and expansion project, as well as the associated economic hedges (collectively, the “Liquefaction Supply Derivatives”).

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow, fair value or net investment 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, distinguished by the fair value hierarchy levels prescribed by GAAP (in millions):


	Fair Value Measurements as of
	June 30, 2024								December 31, 2023
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total

Liquefaction Supply Derivatives asset (liability)	$	(11)	$	(4)	$	(1,495)	$	(1,510)	$	18	$	1	$	(1,676)	$	(1,657)

We value the Liquefaction Supply Derivatives using a market or option-based approach incorporating present value techniques, as needed, which incorporates observable commodity price curves, when available, and other relevant data.

We include a significant portion of the 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 may use in valuing the asset or liability. To the extent valued using an option pricing model, we consider the future prices of energy units for unobservable periods to be a significant unobservable input to estimated net fair value. In estimating the future prices of energy units, we make judgments about market risk related to liquidity of commodity indices and volatility utilizing available market data. Changes in facts and circumstances or additional information may result in revised estimates and judgments, and actual

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

results may differ from these estimates and judgments. We derive our volatility assumptions based on observed historical settled global LNG market pricing or accepted proxies for global LNG market pricing as well as settled domestic natural gas pricing. Such volatility assumptions also contemplate, as of the balance sheet date, observable forward curve data of such indices, as well as evolving available industry data and independent studies.

In developing our volatility assumptions, we acknowledge that the global LNG industry is inherently influenced by events such as unplanned supply constraints, geopolitical incidents, unusual climate events including drought and uncommonly mild, by historical standards, winters and summers, and real or threatened disruptive operational impacts to global energy infrastructure. Our current estimate of volatility includes the impact of otherwise rare events unless we believe market participants would exclude such events on account of their assertion that those events were specific to our company and deemed within our control. Our fair value estimates incorporate market participant-based assumptions pertaining to certain contractual uncertainties, including those related to the availability of market information for delivery points, as well as the timing of satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. We may recognize changes in fair value through earnings that could significantly impact our results of operations if and when such uncertainties are resolved.

The Level 3 fair value measurements of our natural gas positions within the 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 the Level 3 Liquefaction Supply Derivatives as of June 30, 2024:

Net Fair Value Liability

(in millions)

Valuation Approach

Significant Unobservable Input

Range of Significant Unobservable Inputs / Weighted Average (1)

Liquefaction Supply Derivatives

$(1,495)

Market approach incorporating present value techniques

Henry Hub basis spread

$(0.648) - $0.415 / $0.007

Option pricing model

International LNG pricing spread, relative to Henry Hub (2)

23% - 394% / 151%

(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 the Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of the Level 3 Liquefaction Supply Derivatives (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Balance, beginning of period	$	(1,635)	$	(2,502)	$	(1,676)	$	(3,719)
Realized and change in fair value gains included in net income (1):
Included in cost of sales, existing deals (2)	106		173		98		1,116
Included in cost of sales, new deals (3)	7		3		7		5
Purchases and settlements:
Purchases (4)	—		—		—		—
Settlements (5)	27		71		76		340


Transfers out of level 3 (6)	—		—		—		3
Balance, end of period	$	(1,495)	$	(2,255)	$	(1,495)	$	(2,255)
Favorable changes in fair value relating to instruments still held at the end of the period	$	113	$	176	$	105	$	1,121

(1)Does not include the realized value associated with derivative instruments that settle through physical delivery, as settlement is equal to the contractually fixed price from trade date multiplied by contractual volume. See settlements line item in this table.

(2)Impact to earnings on deals that existed at the beginning of the period and continue to exist at the end of the period.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

(3)Impact to earnings on deals that were entered into during the reporting period and continue to exist at the end of the period.

(4)Includes any day one gain (loss) recognized during the reporting period on deals that were entered into during the reporting period which continue to exist at the end of the period.

(5)Roll-off in the current period of amounts recognized in our Consolidated Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period.

(6)Transferred out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.

Liquefaction Supply Derivatives

We hold Liquefaction Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. As of June 30, 2024, the remaining fixed terms of the Liquefaction Supply Derivatives ranged up to approximately 15 years, some of which commence or accelerate upon the satisfaction of certain events or development of infrastructure to support natural gas gathering and transport.

The forward notional amount for the Liquefaction Supply Derivatives was approximately 6,053 TBtu and 6,245 TBtu as of June 30, 2024 and December 31, 2023, respectively, inclusive of amounts under contracts with unsatisfied contractual conditions, and exclusive of extension options that were uncertain to be taken as of June 30, 2024.

The following table shows the effect and location of the Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations (in millions):


	Gain Recognized in Consolidated Statements of Operations
Consolidated Statements of Operations Location (1)	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023

Cost of sales	$	109	$	242	$	164	$	1,502

(1)Does not include the realized value associated with the Liquefaction Supply Derivatives 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

All existing 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 those 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.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the fair value and location of the Liquefaction Supply Derivatives on our Consolidated Balance Sheets (in millions):




	Fair Value Measurements as of (1)
Consolidated Balance Sheets Location	June 30, 2024		December 31, 2023
Current derivative assets	$	18	$	30
Derivative assets	26		40
Total derivative assets	44		70

Current derivative liabilities	(235)		(196)
Derivative liabilities	(1,319)		(1,531)
Total derivative liabilities	(1,554)		(1,727)

Derivative liability, net	$	(1,510)	$	(1,657)

(1)Does not include collateral posted with counterparties by us of $27 million and zero as of June 30, 2024 and December 31, 2023, respectively, which is included in other current assets, net on our Consolidated Balance Sheets, and collateral posted by counterparties to us of zero and $4 million as of June 30, 2024 and December 31, 2023, respectively, which is included in other current liabilities on 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
	June 30, 2024		December 31, 2023
Gross assets	$	62	$	88
Offsetting amounts	(18)		(18)
Net assets	$	44	$	70

Gross liabilities	$	(1,601)	$	(1,746)
Offsetting amounts	47		19
Net liabilities	$	(1,554)	$	(1,727)

NOTE 7—ACCRUED LIABILITIES

Accrued liabilities consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Natural gas purchases	$	335	$	464
Interest costs and related debt fees	238		256
LNG terminal and related pipeline costs	69		77
Other accrued liabilities	31		9
Total accrued liabilities	$	673	$	806

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 8—DEBT

Debt consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
SPL:
Senior Secured Notes:


5.750% due 2024	$	—	$	300
5.625% due 2025	800		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
4.746% weighted average rate due 2037	1,782		1,782
Total SPL Senior Secured Notes	8,932		10,432

Revolving credit and guaranty agreement (the “SPL Revolving Credit Facility”)	—		—
Total debt - SPL	8,932		10,432

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
5.950% due 2033	1,400		1,400
5.750% due 2034	1,200		—
Total CQP Senior Notes	6,800		5,600

Revolving credit and guaranty agreement (the “CQP Revolving Credit Facility”)	—		—
Total debt - CQP	6,800		5,600
Total debt	15,732		16,032

Current debt, net of unamortized debt issuance costs	(798)		(300)

Unamortized discount and debt issuance costs	(131)		(126)
Total long-term debt, net of unamortized discount and debt issuance costs	$	14,803	$	15,606

Credit Facilities

Below is a summary of our credit facilities outstanding as of June 30, 2024 (in millions):


	SPL Revolving Credit Facility		CQP Revolving Credit Facility
Total facility size	$	1,000	$	1,000
Less:
Outstanding balance	—		—

Letters of credit issued	238		—
Available commitment	$	762	$	1,000

Priority ranking	Senior secured		Senior unsecured
Interest rate on available balance (1)	SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.75% or base rate plus 0.0% - 0.75%		SOFR plus credit spread adjustment of 0.1%, plus margin of 1.125% - 2.0% or base rate plus 0.125% - 1.0%

Commitment fees on undrawn balance (1)	0.075% - 0.30%		0.10% - 0.30%
Maturity date	June 23, 2028		June 23, 2028

(1)The margin on the interest rate and the commitment fees is subject to change based on the applicable entity’s credit rating.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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. SPL is restricted from making distributions under agreements governing its indebtedness generally until, among other requirements, appropriate reserves have been established for debt service using cash or letters of credit and a historical debt service coverage ratio and projected debt service coverage ratio of at least 1.25:1.00 is satisfied.

As of June 30, 2024, 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 June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Total interest cost	$	204	$	209	$	408	$	419
Capitalized interest	(2)		(2)		(4)		(4)
Total interest expense, net of capitalized interest	$	202	$	207	$	404	$	415

Fair Value Disclosures

The following table shows the carrying amount and estimated fair value of our senior notes (in millions):


	June 30, 2024				December 31, 2023
	Carrying Amount		Estimated Fair Value (1)		Carrying Amount		Estimated Fair Value (1)
Senior notes	$	15,732	$	15,158	$	16,032	$	15,636

(1)As of both June 30, 2024 and December 31, 2023, $1.3 billion of the fair value of our senior notes were classified as Level 3 since these senior notes were valued by applying an unobservable illiquidity adjustment to the price derived from trades or indicative bids of instruments with similar terms, maturities and credit standing. The remainder of the fair value of our senior notes are classified as Level 2, based on prices derived from trades or indicative bids of the instruments.

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.

NOTE 9—REVENUES

The following table represents a disaggregation of revenue earned (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Revenues from contracts with customers
LNG revenues	$	1,454	$	1,415	$	3,174	$	3,521
LNG revenues—affiliate	391		469		915		1,230

Regasification revenues	34		33		68		67
Other revenues	15		16		32		32

Total revenues from contracts with customers	$	1,894	$	1,933	$	4,189	$	4,850

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Contract Assets and Liabilities

The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets, net and other non-current assets, net on our Consolidated Balance Sheets (in millions):


	June 30,		December 31,

	2024		2023
Contract assets, net of current expected credit losses	$	1	$	1

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Consolidated Balance Sheets (in millions):


	Six Months Ended June 30, 2024

Deferred revenue, beginning of period	$	190
Cash received but not yet recognized in revenue	95
Revenue recognized from prior period deferral	(114)
Deferred revenue, end of period	$	171

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):


	Six Months Ended June 30, 2024

Deferred revenue—affiliate, beginning of period	$	5
Cash received but not yet recognized in revenue	1
Revenue recognized from prior period deferral	—
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:


	June 30, 2024			December 31, 2023
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues (2)	$	45.9	7	$	47.6	8
LNG revenues—affiliate	1.0		1	1.4		2
Regasification revenues	0.6		3	0.7		3
Total revenues	$	47.5		$	49.7

(1)The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

(2)We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching FID on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are included in the transaction price above when the conditions are considered probable of being met and consideration is not otherwise constrained from ultimate pricing and receipt.

The following potential future sources of revenue are omitted from the table above under exemptions we have elected: (1) all performance obligations that are part of a contract that has an original expected duration of one year or less and (2) substantially all variable consideration under our SPAs and TUAs as well as 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 the underlying variable index, primarily Henry Hub, throughout the contract terms, to the extent customers elect to take delivery of their LNG, and

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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. Additionally, we have excluded variable consideration related to volumes that are contractually subject to additional liquefaction capacity beyond what is currently in construction or operation.

The following table summarizes the amount of variable consideration earned under contracts with customers included in the table above:


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
LNG revenues	46	%	49	%	48	%	57	%
LNG revenues—affiliate	61	%	66	%	62	%	70	%
Regasification revenues	8	%	7	%	8	%	7	%

NOTE 10—RELATED PARTY TRANSACTIONS

Below is a summary of our transactions with our affiliates and other related parties, all in the ordinary course of business, as reported on our Consolidated Statements of Operations (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
LNG revenues—affiliate
SPAs and Letter Agreements with Cheniere Marketing	$	391	$	468	$	915	$	1,229
Contracts for Sale and Purchase of Natural Gas and LNG with other affiliates	—		1		—		1
Total LNG revenues—affiliate	391		469		915		1,230










Cost of sales—affiliate
Cheniere Marketing Agreements	—		—		4		—
Contracts for Sale and Purchase of Natural Gas and LNG	—		1		—		18
Total cost of sales—affiliate	—		1		4		18






Operating and maintenance expense—affiliate

Services Agreements (see Note 1)	39		38		82		82



Operating and maintenance expense—related party
Natural Gas Transportation and Storage Agreements (1)	16		14		29		30

General and administrative expense—affiliate
Services Agreements (see Note 1)	23		24		45		46

Other operating costs and expenses—affiliate
Services Agreements (see Note 1)	1		—		1		—

(1)This related party is partially owned by Brookfield, who indirectly owns a portion of our limited partner interests.

Assets and liabilities arising from the agreements with affiliates and other related parties referenced in the above table are classified as affiliate and related party, respectively, on our Consolidated Balance Sheets.

Disclosures relating to future consideration under revenue contracts with affiliates is included in Note 9—Revenues.

See our annual report on Form 10-K for the fiscal year ended December 31, 2023 for additional information regarding the agreements referenced in the above table, as well as a description of other agreements we have with our affiliates, including the Terminal Marine Services Agreement. Under this agreement, Tug Services distributed $3 million and $2 million during the three months ended June 30, 2024 and 2023, respectively, and $4 million and $4 million during the six months ended June 30,

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

2024 and 2023, respectively, to Cheniere Terminals, which is recognized as part of the distributions to our general partner interest holders on our Consolidated Statements of Partners’ Deficit.

NOTE 11—NET INCOME PER COMMON UNIT

Net income per common unit for a given period is based on the distributions we incur to the common unitholders with respect to earnings or losses of the reporting period plus an allocation of undistributed net income or loss based on provisions of the partnership agreement, divided by the weighted average number of common units outstanding. Distributions declared by us during the period are presented on the Consolidated Statements of Partners’ Deficit. On July 26, 2024, we declared a cash distribution of $0.810 per common unit to unitholders of record as of August 7, 2024, and the related general partner distribution, to be paid on August 14, 2024 with respect to the three months ended June 30, 2024. These distributions consist of a base amount of $0.775 per unit and a variable amount of $0.035 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 in the current period even though cash distributions are not necessarily derived from current period earnings.

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table provides a reconciliation of net income and the allocation of net income to the common units, the general partner units and IDRs for purposes of computing basic and diluted net income per unit (in millions, except per unit data).



	Total		Limited Partner Common Units		General Partner Units		IDR
Three Months Ended June 30, 2024
Net income	$	570
Declared distributions	501		392		10		99
Assumed allocation of undistributed net income (1)	$	69	67		1		—
Assumed allocation of net income			$	459	$	11	$	99

Weighted average units outstanding			484.0
Basic and diluted net income per unit			$	0.95

Three Months Ended June 30, 2023
Net income	$	622
Declared distributions	714		498		15		201
Assumed allocation of undistributed net loss (1)	$	(92)	(91)		(1)		—
Assumed allocation of net income			$	407	$	14	$	201

Weighted average units outstanding			484.0
Basic and diluted net income per unit			$	0.84

Six Months Ended June 30, 2024
Net income	$	1,252
Declared distributions	1,002		784		20		198
Assumed allocation of undistributed net income (1)	$	250	245		5		—
Assumed allocation of net income			$	1,029	$	25	$	198

Weighted average units outstanding			484.0
Basic and diluted net income per unit			$	2.13


Six Months Ended June 30, 2023
Net income	$	2,557
Declared distributions	1,428		997		29		402

Assumed allocation of undistributed net income (1)	$	1,129	1,106		23		—
Assumed allocation of net income			$	2,103	$	52	$	402

Weighted average units outstanding			484.0
Basic and diluted net income per unit			$	4.35

(1)Under our partnership agreement, the IDRs participate in net income only to the extent of the amount of cash distributions actually declared, thereby excluding the IDRs from participating in undistributed net income (loss).

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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 12—CUSTOMER CONCENTRATION

The concentration of our customer credit risk in excess of 10% of total revenues and/or trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses was as follows:


	Percentage of Total Revenues from External Customers				Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers
	Three Months Ended June 30,		Six Months Ended June 30,		June 30,	December 31,

	2024	2023	2024	2023		2024	2023
Customer A	25%	24%	24%	26%		22%	22%
Customer B	12%	15%	14%	16%		*	16%
Customer C	16%	15%	15%	15%		15%	12%
Customer D	13%	14%	13%	15%		14%	15%
Customer E	11%	12%	11%	11%		*	12%

* Less than 10%

NOTE 13—SUPPLEMENTAL CASH FLOW INFORMATION

The following table provides supplemental disclosure of substantive cash flow information (in millions):


	Six Months Ended June 30,
	2024		2023
Cash paid during the period for interest on debt, net of amounts capitalized	$	405	$	432

Non-cash investing activity (1):
Unpaid purchases of property, plant and equipment, net	23		17
Right-of-use assets obtained in exchange for lease liabilities:
Operating lease liabilities (2)	36		—
Finance lease liabilities (3)	74		—

(1)Reflects unpaid portion, as of the end of each period, of assets and liabilities recognized during the respective periods.

(2)Includes $15 million reclassified from finance leases to operating leases during the six months ended June 30, 2024, as a result of modifications of the underlying tug vessel leases.

(3)Includes $33 million reclassified from operating leases to finance leases during the six months ended June 30, 2024, as a result of modifications of the underlying tug vessel leases.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Information Regarding Forward-Looking Statements

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements.” All statements, other than statements of historical or present facts or conditions, included herein or incorporated herein by reference are “forward-looking statements.” Included among “forward-looking statements” are, among other things:

•statements regarding our ability to pay distributions to our unitholders;

•statements regarding our expected receipt of cash distributions from SPLNG, SPL or CTPL;

•statements that we expect to commence or complete construction of our proposed LNG terminal, liquefaction facility, pipeline facility or other projects, or any expansions or portions thereof, by certain dates, or at all;

•statements regarding future levels of domestic and international natural gas production, supply or consumption or future levels of LNG imports into or exports from North America and other countries worldwide or purchases of natural gas, regardless of the source of such information, or the transportation or other infrastructure or demand for and prices related to natural gas, LNG or other hydrocarbon products;

•statements regarding any financing transactions or arrangements, or our ability to enter into such transactions;

•statements regarding our future sources of liquidity and cash requirements;

•statements relating to the construction of our Trains, including statements concerning the engagement of any EPC contractor or other contractor and the anticipated terms and provisions of any agreement with any EPC or other contractor, and anticipated costs related thereto;

•statements regarding any SPA or other agreement to be entered into or performed substantially in the future, including any revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification, natural gas liquefaction or storage capacities that are, or may become, subject to contracts;

•statements regarding counterparties to our commercial contracts, construction contracts and other contracts;

•statements regarding our planned development and construction of additional Trains, including the financing of such Trains;

•statements that our Trains, when completed, will have certain characteristics, including amounts of liquefaction capacities;

•statements regarding our business strategy, our strengths, our business and operation plans or any other plans, forecasts, projections, or objectives, including anticipated revenues, capital expenditures, maintenance and operating costs and cash flows, any or all of which are subject to change;

•statements relating to our goals, commitments and strategies in relation to environmental matters;

•statements regarding legislative, governmental, regulatory, administrative or other public body actions, approvals, requirements, permits, applications, filings, investigations, proceedings or decisions; and

•any other statements that relate to non-historical or future information.

All of these types of statements, other than statements of historical or present facts or conditions, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “achieve,” “anticipate,” “believe,” “contemplate,” “continue,” “estimate,” “expect,” “intend,” “plan,” “potential,” “predict,” “project,” “pursue,” “target,” the negative of such terms or other comparable terminology. The forward-looking statements contained in this quarterly report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe that such estimates are reasonable, they are inherently uncertain and involve a number of risks and uncertainties beyond our control. In addition, assumptions may prove to be inaccurate. We caution that the forward-looking statements contained in this quarterly report are not guarantees of future performance and that such statements may not be realized or the forward-looking statements or events may not occur. Actual results may differ materially

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from those anticipated or implied in forward-looking statements as a result of a variety of factors described in this quarterly report and in the other reports and other information that we file with the SEC, including those discussed under “Risk Factors” in our annual report on Form 10-K for the fiscal year ended December 31, 2023. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. These forward-looking statements speak only as of the date made, and other than as required by law, we undertake no obligation to update or revise any forward-looking statement or provide reasons why actual results may differ, whether as a result of new information, future events or otherwise.

Introduction

The following discussion and analysis presents management’s view of our business, financial condition and overall performance and should be read in conjunction with our Consolidated Financial Statements and the accompanying notes. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future.

Our discussion and analysis includes the following subjects:

•Overview

•Overview of Significant Events

•Results of Operations

•Liquidity and Capital Resources

•Summary of Critical Accounting Estimates

•Recent Accounting Standards

Overview

We are a publicly traded Delaware limited partnership formed by Cheniere. We provide clean, secure and affordable LNG to integrated energy companies, utilities and energy trading companies around the world. We aspire to conduct our business in a safe and responsible manner, delivering a reliable, competitive and integrated source of LNG to our customers.

LNG is natural gas (methane) in liquid form. The LNG we produce is shipped all over the world, converted back into natural gas (called “regasification”) and then transported via pipeline to homes and businesses and used as an energy source that is essential for heating, cooking, other industrial uses and back up for intermittent energy sources. Natural gas is a cleaner-burning, abundant and affordable source of energy. When LNG is converted back to natural gas, it can be used instead of coal, which reduces the amount of pollution traditionally produced from burning fossil fuels, like sulfur dioxide and particulate matter that enters the air we breathe. Additionally, compared to coal, it produces significantly fewer carbon emissions. By liquefying natural gas, we are able to reduce its volume by 600 times so that we can load it onto special LNG carriers designed to keep the LNG cold and in liquid form for efficient transport overseas.

We own a natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal”), one of the largest LNG production facilities in the world, which has six operational Trains, 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 with aggregate capacity of approximately 17 Bcfe and vaporizers with regasification capacity of approximately 4 Bcf/d, as well as three marine berths, two of which can accommodate vessels with nominal capacity of up to 266,000 cubic meters and the third berth which can accommodate vessels with nominal capacity of up to 200,000 cubic meters. We also own a 94-mile natural gas supply pipeline through our subsidiary, CTPL, that interconnects the Sabine Pass LNG Terminal with several large interstate and intrastate pipelines (the “Creole Trail Pipeline”).

Our long-term customer arrangements form the foundation of our business and provide us with significant, stable, long-term cash flows. We have contracted most of our anticipated production capacity under SPAs, in which our customers are generally required to pay a fixed fee with respect to the contracted volumes irrespective of their election to cancel or suspend deliveries of LNG cargoes, and under IPM agreements, in which a gas producer sells natural gas to us on a global LNG or natural gas index price, less a fixed liquefaction fee, shipping and other costs. The SPAs also have a variable fee component,

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which is generally structured to cover the cost of natural gas purchases, transportation and liquefaction fuel consumed to produce LNG. Since we procure most of our feedstock for LNG production from the U.S., the structure of these contracts helps limit our exposure to fluctuations in U.S. natural gas prices. Through our SPAs and IPM agreement, we have contracted approximately 80% of the total anticipated production from the Liquefaction Project with approximately 14 years of weighted average remaining life as of June 30, 2024, excluding volumes that are contractually subject to additional liquefaction capacity beyond what is currently in construction or operation.

We remain focused on safety, operational excellence and customer satisfaction. Increasing demand for LNG has allowed us to expand our liquefaction infrastructure in a financially disciplined manner. We have increased available liquefaction capacity at our Liquefaction Project as a result of debottlenecking and other optimization projects. We believe these factors provide a foundation for additional growth in our portfolio of customer contracts in the future. We hold a significant land position at the Sabine Pass LNG Terminal, which provides opportunity for further liquefaction capacity expansion. We are developing an expansion adjacent to the Liquefaction Project with a total production capacity of up to approximately 20 mtpa of LNG, inclusive of estimated debottlenecking opportunities (the “SPL Expansion Project”). In February 2024, certain of our subsidiaries submitted an application to the FERC under the Natural Gas Act (the “NGA”) for authorization to site, construct and operate the SPL Expansion Project, as well as an application to the DOE requesting authorization to export LNG to FTA countries and non-FTA countries, both of which applications exclude debottlenecking. The development of the SPL Expansion Project 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 a positive FID is made.

Additionally, we are committed to the management of our most important ESG impacts, risks and opportunities. In August 2023, Cheniere published The Power of Connection, its fourth Corporate Responsibility (“CR”) report, which details its approach and progress on ESG matters. Cheniere’s CR report is available at cheniere.com/our-responsibility/reporting-center. Information on Cheniere’s website, including the CR report, is not incorporated by reference into this Quarterly Report on Form 10-Q.

Overview of Significant Events

Our significant events since January 1, 2024 and through the filing date of this Form 10-Q include the following:

Strategic

•In February 2024, certain of our subsidiaries submitted an application to the FERC under the NGA for authorization to site, construct and operate the SPL Expansion Project, as well as an application to the DOE requesting authorization to export LNG to FTA countries and non-FTA countries, both of which applications exclude debottlenecking.

Operational

•As of August 2, 2024, approximately 2,600 cumulative LNG cargoes totaling approximately 180 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Project.

Financial

•On July 26, 2024, with respect to the second quarter of 2024, we declared a cash distribution of $0.810 per common unit to unitholders of record as of August 7, 2024, and the related general partner distribution, to be paid on August 14, 2024. These distributions consist of a base amount of $0.775 per unit and a variable amount of $0.035 per unit.

•In May 2024, we issued $1.2 billion aggregate principal amount of 5.750% Senior Notes due 2034 (the “2034 CQP Senior Notes”). In June 2024, the net proceeds, together with cash on hand, were used to retire $1.2 billion outstanding aggregate principal amount of SPL’s 5.625% Senior Secured Notes due 2025 (the “2025 SPL Senior Notes”).

•In May 2024, in connection with the 2034 CQP Senior Notes issuance, Moody’s Ratings (“Moody’s”) upgraded our issuer credit rating to Baa2 from Ba1 and revised our outlook to stable from positive. Moody’s also upgraded SPL’s issuer credit rating to Baa1 from Baa2 and revised SPL’s outlook to stable from positive.

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•During the three and six months ended June 30, 2024, SPL repaid $150 million and $300 million, respectively, of outstanding aggregate principal amount of its 5.750% Senior Secured Notes due 2024 (the “2024 SPL Senior Notes”).

Results of Operations


	Three Months Ended June 30,						Six Months Ended June 30,
(in millions, except per unit data)	2024		2023		Variance		2024		2023		Variance
Revenues
LNG revenues	$	1,454	$	1,415	$	39	$	3,174	$	3,521	$	(347)
LNG revenues—affiliate	391		469		(78)		915		1,230		(315)

Regasification revenues	34		33		1		68		67		1

Other revenues	15		16		(1)		32		32		—

Total revenues	1,894		1,933		(39)		4,189		4,850		(661)

Operating costs and expenses
Cost of sales (excluding items shown separately below)	661		603		58		1,625		916		709
Cost of sales—affiliate	—		1		(1)		4		18		(14)

Operating and maintenance expense	210		263		(53)		410		469		(59)
Operating and maintenance expense—affiliate	39		38		1		82		82		—
Operating and maintenance expense—related party	16		14		2		29		30		(1)


General and administrative expense	3		3		—		6		6		—
General and administrative expense—affiliate	23		24		(1)		45		46		(1)
Depreciation and amortization expense	170		167		3		338		334		4
Other operating costs and expenses	5		2		3		8		2		6
Other operating costs and expenses—affiliate	1		—		1		1		—		1
Total operating costs and expenses	1,128		1,115		13		2,548		1,903		645

Income from operations	766		818		(52)		1,641		2,947		(1,306)

Other income (expense)
Interest expense, net of capitalized interest	(202)		(207)		5		(404)		(415)		11
Loss on modification or extinguishment of debt	(3)		(2)		(1)		(3)		(2)		(1)
Interest and dividend income	9		13		(4)		18		27		(9)


Total other expense	(196)		(196)		—		(389)		(390)		1

Net income	$	570	$	622	$	(52)	$	1,252	$	2,557	$	(1,305)

Basic and diluted net income per common unit	$	0.95	$	0.84	$	0.11	$	2.13	$	4.35	$	(2.22)

Volumes loaded and recognized from the Liquefaction Project


	Three Months Ended June 30,			Six Months Ended June 30,
	2024	2023	Variance	2024	2023	Variance

LNG volumes loaded and recognized as revenues (in TBtu)	372	353	19	789	756	33

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Net income

Net income declined by $52 million between the three months ended June 30, 2024 and 2023, primarily as a result of decreased revenues, as further described in Revenues below. Substantially all of the decline in net income of $1.3 billion between the six months ended June 30, 2024 and 2023 was attributable to unfavorable changes in fair value and settlements of derivatives, principally attributable to our IPM agreement with Tourmaline Oil Marketing Corp, where the associated gains decreased from $1.2 billion during the six months ended June 30, 2023 to $205 million during the six months ended June 30, 2024, due to the impact on fair value of moderating changes in volatility in international gas prices during the current period relative to the same period of 2023. Excluding the aforementioned changes in fair value and settlements of derivatives, LNG revenues, net of cost of sales was relatively consistent between the six months ended June 30, 2024 and 2023.

The following is an additional discussion of the significant drivers of the variance in net income by line item:

Revenues

We had $39 million and $661 million decreases in revenues between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023, which was primarily attributable to $118 million and $854 million decreases between the three and six months ended June 30, 2024, respectively, from lower pricing per MMBtu as a result of declining Henry Hub pricing, partially offset by $96 million and $206 million increases, respectively, from higher production volume largely due to reduced operating and maintenance activities compared to the same periods of 2023 and cooler weather.

Operating costs and expenses

Operating costs and expenses remained relatively consistent between the three months ended June 30, 2024 and 2023. The $645 million increase between the six months ended June 30, 2024 and 2023 was primarily attributable to a $1.4 billion unfavorable variance from changes in fair value of derivatives included in cost of sales, from $1.5 billion in the six months ended June 30, 2023 to $147 million in the six months ended June 30, 2024, primarily due to moderating volatility in international gas prices during the current period resulting in decreased non-cash gains in fair value of our commodity derivatives indexed to such prices, specifically associated with the Tourmaline IPM Agreement as discussed above under Net income. This increase was partially offset by a $642 million decrease in cost of sales excluding the effect of derivative changes described above, primarily as a result of a $562 million decrease in cost of natural gas feedstock largely due to lower U.S. natural gas prices.

Significant factor affecting our results of operations

Below is a significant factor that affects our results of operations.

Gains and losses on derivative instruments

Derivative instruments are utilized to manage our exposure to commodity-related marketing and price risks and are reported at fair value on our Consolidated Financial Statements. For commodity derivative instruments related to our IPM agreements, the underlying LNG sales being economically hedged are accounted for under the accrual method of accounting, whereby revenues expected to be derived from the future LNG sales are recognized only upon delivery or realization of the underlying transaction. Notwithstanding the operational intent to mitigate risk exposure over time, the recognition of derivative instruments at fair value has the effect of recognizing gains or losses relating to future period exposure, and given the significant volumes, long-term duration and volatility in price basis for certain of our derivative contracts, the use of derivative instruments may result in continued volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant factors that may be outside of our control. For example, as described in Note 6—Derivative Instruments of our Notes to Consolidated Financial Statements, the fair value of the Liquefaction Supply Derivatives, as applicable, incorporates market participant-based assumptions pertaining to certain contractual uncertainties, including those related to the availability of market information for delivery points, which may require future development of infrastructure, as well as the timing of satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. We may recognize changes in fair value through earnings that could significantly impact our results of operations if and when such uncertainties are resolved.

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Liquidity and Capital Resources

The following information describes our ability to generate and obtain adequate amounts of cash to meet our requirements in the short term and the long term. In the short term, we expect to meet our cash requirements using operating cash flows and available liquidity, consisting of cash and cash equivalents, restricted cash and cash equivalents and available commitments under our credit facilities. Additionally, we expect to meet our long term cash requirements by using operating cash flows and other future potential sources of liquidity, which may include debt offerings by us or our subsidiaries and equity offerings by us. The table below provides a summary of our available liquidity (in millions). Future material sources of liquidity are discussed below.


	June 30, 2024


Cash and cash equivalents	$	351
Restricted cash and cash equivalents designated for the Liquefaction Project	68

Available commitments under our credit facilities (1):

SPL Revolving Credit Facility	762
CQP Revolving Credit Facility	1,000

Total available commitments under our credit facilities	1,762

Total available liquidity	$	2,181

(1)Available commitments represent total commitments less loans outstanding and letters of credit issued under each of our credit facilities as of June 30, 2024. See Note 8—Debt of our Notes to Consolidated Financial Statements for additional information on our credit facilities and other debt instruments.

Our liquidity position subsequent to June 30, 2024 will be driven by future sources of liquidity and future cash requirements. For a discussion of our future sources and uses of liquidity, see the liquidity and capital resources disclosures in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

Although our sources and uses of cash are presented below from a consolidated standpoint, we and our subsidiary SPL operate with independent capital structures. Certain restrictions or requirements under debt instruments executed by SPL limit its ability to distribute cash, including the following:

•SPL is required to deposit all cash received into restricted cash and cash equivalents accounts under certain of their debt agreements. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments. In addition, SPL’s operating costs are managed by subsidiaries of Cheniere under affiliate agreements, which may require SPL to advance cash to the respective affiliates; and

•SPL is restricted by affirmative and negative covenants included in certain of its debt agreements in its ability to make certain payments, including distributions, unless specific requirements are satisfied.

Despite the restrictions noted above, we believe that sufficient flexibility exists to enable each independent capital structure to meet its currently anticipated cash requirements. The sources of liquidity at SPL primarily fund the cash requirements of SPL, and any remaining liquidity not subject to restriction, as supplemented by liquidity provided by our other operations, is available to enable CQP to meet its cash requirements.

Supplemental Guarantor Information

Certain debt obligations of CQP (the “Guaranteed Obligations”) consist of the CQP Revolving Credit Facility, $1.5 billion of 4.500% Senior Notes due 2029, $1.5 billion of 4.000% Senior Notes due 2031, $1.2 billion of 3.25% Senior Notes due 2032, and $1.4 billion of 5.950% Senior Notes due 2033 (the “2033 CQP Senior Notes” and each of the foregoing series together with the 2033 CQP Senior Notes, the “CQP Senior Notes”), all of which are jointly and severally guaranteed by certain subsidiaries of CQP, as prescribed within the respective debt agreements (each a “Guarantor” and collectively, the “CQP Guarantors”).

The CQP Guarantors’ guarantees of such obligations are full and unconditional, subject to certain release provisions including, as applicable, (1) the sale, disposition or transfer (by merger, consolidation or otherwise) of the capital stock or all or substantially all of the assets of a Guarantor, (2) the liquidation or dissolution of a Guarantor, (3) following the release of a

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Guarantor from another guarantee that resulted in the creation of its guarantee of the Guaranteed Obligation and (4) the legal defeasance or satisfaction and discharge of obligations under the indenture governing the CQP Senior Notes. In the event of a default in payment of the principal or interest by us, whether at maturity of the respective debt obligation or by declaration of acceleration, call for redemption or otherwise, legal proceedings may be instituted against the CQP Guarantors to enforce the guarantee.

The Guaranteed Obligations contain affirmative and negative covenants that are customary for the respective debt instrument, including, with limited exceptions, restrictions on CQP’s and the CQP Guarantors’ ability to incur additional indebtedness and/or liens, enter into hedging arrangements and/or engage in transactions with affiliates. The Guaranteed Obligations also include events of default that are customary for the respective debt instrument, which are subject to customary grace periods and materiality standards.

The rights of holders of the Guaranteed Obligations against the CQP Guarantors may be limited under the U.S. Bankruptcy Code or state fraudulent transfer or conveyance law. Each guarantee contains a provision intended to limit the CQP Guarantor’s liability to the maximum amount that it could incur without causing the incurrence of obligations under its guarantee to be a fraudulent conveyance or transfer under U.S. federal or state law. However, there can be no assurance as to what standard a court will apply in making a determination of the maximum liability of the CQP Guarantors. Moreover, this provision may not be effective to protect the guarantee from being voided under fraudulent conveyance laws. There is a possibility that the entire guarantee may be set aside, in which case the entire liability may be extinguished.

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The following tables include summarized financial information of CQP (the “Parent Issuer”), and the CQP Guarantors (together with the Parent Issuer, the “Obligor Group”) on a combined basis. Investments in and equity in the earnings of SPL and, subject to certain conditions governing its guarantee, Sabine Pass LP (collectively with SPL, the “Non-Guarantors”), which are not currently members of the Obligor Group, have been excluded. Intercompany balances and transactions between entities in the Obligor Group have been eliminated. Although the creditors of the Obligor Group have no claim against the Non-Guarantors, the Obligor Group may gain access to the assets of the Non-Guarantors upon bankruptcy, liquidation or reorganization of the Non-Guarantors due to its investment in these entities. However, such claims to the assets of the Non-Guarantors would be subordinated to any claims by the Non-Guarantors’ creditors, including trade creditors.


Summarized Balance Sheets (in millions)	June 30,		December 31,

	2024		2023
ASSETS
Current assets
Cash and cash equivalents	$	351	$	575
Trade receivables from Non-Guarantors	33		55

Other current assets, net	—		39
Current assets—affiliate	126		86
Current assets with Non-Guarantors	42		1
Total current assets	552		756

Property, plant and equipment, net of accumulated depreciation	2,944		2,915
Other non-current assets, net	112		110
Total assets	$	3,608	$	3,781

LIABILITIES
Current liabilities
Due to affiliates	$	143	$	121
Deferred revenue from Non-Guarantors	22		3

Other current liabilities	167		177

Total current liabilities	332		301

Long-term debt, net of premium, discount and debt issuance costs	6,727		5,542
Finance lease liabilities	70		14
Other non-current liabilities	74		67
Non-current liabilities—affiliate	17		18
Total liabilities	$	7,220	$	5,942


Summarized Statement of Operations (in millions)	Six Months Ended June 30, 2024

Revenues	$	100
Revenues from Non-Guarantors	275
Total revenues	375

Operating costs and expenses	132
Operating costs and expenses—affiliate	98
Operating costs and expenses—Non-Guarantors	4
Total operating costs and expenses	234

Income from operations	141
Net income	12

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Sources and Uses of Cash

The following table summarizes the sources and uses of our cash, cash equivalents and restricted cash and cash equivalents (in millions). The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, which are referred to elsewhere in this report. Additional discussion of these items follows the table.


	Six Months Ended June 30,
	2024		2023

Net cash provided by operating activities	$	1,401	$	1,538
Net cash used in investing activities	(69)		(155)
Net cash used in financing activities	(1,544)		(304)












Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents	$	(212)	$	1,079

Operating Cash Flows

The $137 million decrease between the periods was primarily related to lower cash receipts from the sale of LNG cargoes from lower pricing per MMBtu, primarily as a result of decreased Henry Hub pricing. The decrease was partially offset by lower cash outflows for natural gas feedstock, mostly due to lower U.S. natural gas prices.

Investing Cash Flows

Cash outflows for property, plant and equipment during the six months ended June 30, 2024 and 2023 were primarily related to optimization and other site improvement projects.

Financing Cash Flows

The following table summarizes our financing activities (in millions):


	Six Months Ended June 30,
	2024		2023
Proceeds from issuances of debt	$	1,228	$	1,397
Repayments of debt	(1,530)		(200)
Debt issuance and other financing costs	(15)		(27)
Debt extinguishment costs	—		—

Distributions	(1,224)		(1,472)
Other	(3)		(2)
Net cash used in financing activities	$	(1,544)	$	(304)

Debt Activity

During the six months ended June 30, 2024, we issued an aggregate amount of $1.2 billion of 2034 CQP Senior Notes and used the proceeds and cash on hand to retire $1.2 billion outstanding aggregate principal amount of the 2025 SPL Senior Notes, as well as repaid the outstanding aggregate principal amount of $300 million of the 2024 SPL Senior Notes with cash on hand. During the six months ended June 30, 2023, we issued an aggregate amount of $1.4 billion of 5.950% Senior Notes due 2033 and repurchased $200 million of the 2024 SPL Senior Notes in the open market.

Cash Distributions to Unitholders

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). Our available cash is our cash on hand at the end of a quarter less the amount of any reserves established by our general partner. All distributions paid to date have been made from accumulated operating surplus.

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The following provides a summary of distributions paid by us during the six months ended June 30, 2024 and 2023:


				Total Distribution (in millions)
Date Paid	Period Covered by Distribution	Distribution Per Common Unit		Common Units		General Partner Units		Incentive Distribution Rights


May 15, 2024	January 1 - March 31, 2024	$	0.810	$	392	$	10	$	99
February 14, 2024	October 1 - December 31, 2023	1.035		501		14		204



May 15, 2023	January 1 - March 31, 2023	1.030		499		14		201
February 14, 2023	October 1 - December 31, 2022	1.070		518		15		220

In addition, Tug Services distributed $4 million and $4 million during the six months ended June 30, 2024 and 2023, respectively, to Cheniere Terminals in accordance with their terminal marine service agreement, which is recognized as part of the distributions to the holder of our general partner interest.

On July 26, 2024, with respect to the second quarter of 2024, we declared a cash distribution of $0.810 per common unit to unitholders of record as of August 7, 2024, and the related general partner distribution, to be paid on August 14, 2024. These distributions consist of a base amount of $0.775 per unit and a variable amount of $0.035 per unit.

Summary of Critical Accounting Estimates

The preparation of Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

Recent Accounting Standards

For a summary of recently issued accounting standards, see Note 1—Nature of Operations and Basis of Presentation of our Notes to Consolidated Financial Statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Marketing and Trading Commodity Price Risk

We have commodity derivatives consisting of natural gas supply contracts for the operation of the Liquefaction Project (the “Liquefaction Supply Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location as follows (in millions):


	June 30, 2024				December 31, 2023
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Liquefaction Supply Derivatives	$	(1,510)	$	339	$	(1,657)	$	362

See Note 6—Derivative Instruments of our Notes to Consolidated Financial Statements for additional details about our derivative instruments.

ITEM 4. CONTROLS AND PROCEDURES

We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our general partner’s management, including our general partner’s Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation,

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our general partner’s Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective.

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. There have been no material changes to the legal proceedings disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

ITEM 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

ITEM 5. OTHER INFORMATION

Rule 10b5-1 under the Exchange Act provides an affirmative defense that enables prearranged transactions in securities in a manner that avoids concerns about initiating transactions at a future date while possibly in possession of material nonpublic information. Our Insider Trading Policy permits the directors and executive officers of our general partner to enter into trading plans designed to comply with Rule 10b5-1. During the three-month period ending June 30, 2024, none of the executive officers or directors of our general partner adopted or terminated a Rule 10b5-1 trading plan or adopted or terminated a non-Rule 10b5-1 trading arrangement (as defined in Item 408(c) of Regulation S-K).

ITEM 6. EXHIBITS

Exhibit No.

Description

4.1

Ninth Supplemental Indenture, dated as of May 22, 2024, among CQP, the guarantors party thereto and The Bank of New York Mellon, as Trustee under the Indenture (incorporated by reference to Exhibit 4.1 to the CQP's Current Report on Form 8-K (SEC File No. 001-33366), filed on May 22, 2024)

10.1

Registration Rights Agreement, dated as of May 22, 2024, among CQP, the guarantor party thereto, BofA Securities, Inc., Citigroup Global Markets Inc., ING Financial Markets LLC, MUFG Securities Americas Inc., SMBC Nikko Securities America, Inc. and Standard Chartered Bank (incorporated by reference to Exhibit 10.1 to CQP's Current Report on Form 8-K (SEC File No. 001-33366), filed on May 22, 2024)

22.1

List of Issuers and Guarantor Subsidiaries (Incorporated by reference to Exhibit 22.1 to the Partnership's Annual Report on Form 10-K (SEC File No. 001-33366), filed on February 22, 2024)

31.1*

Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

31.2*

Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

32.1**

Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2**

Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.INS*

XBRL Instance Document

101.SCH*

XBRL Taxonomy Extension Schema Document

101.CAL*

XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*

XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*

XBRL Taxonomy Extension Labels Linkbase Document

101.PRE*

XBRL Taxonomy Extension Presentation Linkbase Document

104*

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)



*			Filed herewith.
**			Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


		CHENIERE ENERGY PARTNERS, L.P.
		By:	Cheniere Energy Partners GP, LLC, its general partner

Date:	August 7, 2024	By:	/s/ Zach Davis
			Zach Davis
			Executive Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)

Date:	August 7, 2024	By:	/s/ David Slack
			David Slack
			Senior Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)