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, 2021~~March 31, 2022

☐ 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 001-16383

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)


Delaware			95-4352386
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

700 Milam Street, Suite 1900

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 Stock, $ 0.003 par value	LNG	NYSE American

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 ~~July 30, 2021,~~April 29, 2022, the issuer had ~~253,606,918~~254,139,054 shares of Common Stock outstanding.

CHENIERE ENERGY, INC.

TABLE OF CONTENTS
























	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Statements of Operations	3
	Consolidated Balance Sheets	4
	Consolidated Statements of Stockholders’ ~~Equity~~Equit y (Defi cit)	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—Restricted Cash	8
	Note 3—~~Accounts~~Trade and Other Receivables, N e tNet of Current Expected Credit Losses	89
	Note 4—Inventory	9
	Note 5—Property, Plant and Equipment, N e tNet of Accumulated Depreciation	9
	Note 6—Derivative Instruments	10

	Note 7—~~Other Non-Current Assets, Ne~~tNon-Controlling Interest and Variable Interest Entity	15
	Note 8—~~Non-Controlling Interest and Variable Interest Entity~~	16
	~~Note 9—~~Accrued Liabilities	16
	Note ~~10—~~9—Debt	17
	Note 10—Leases	20
	Note 11—~~Leases~~Revenues from Contracts with Customers	21
	Note 12—~~Revenues from Contracts with Customers~~Related Party Transactions	23
	Note 13—~~Related Party Transactions~~Income Taxes	23

	Note 1 4 —Net Income (Loss) per Share Attributable to Common Stockholders	24

	Note 15—Stockholders’ Deficit	24
	Note ~~14—Income Taxes~~1 6 —Customer Concentration	25
	Note ~~15—Share-Based Compensation~~1	267
	~~Note 16—Net Income per Share Attributable to Common Stockholders~~	26

	~~Note 17—Customer Concentration~~	27
	~~Note 18—~~—Supplemental Cash Flow Information	2825

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2926

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	5037

Item 4.	Controls and Procedures	5138

Part II. Other Information
Item 1.	Legal Proceedings	5239

Item 1A.	Risk Factors	5239

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	5240

Item 6.	Exhibits	5341

	Signatures	5442

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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						billion cubic feet
Bcf/d						billion cubic feet per day
Bcf/yr						billion cubic feet per year
Bcfe						billion cubic feet equivalent
DOE						U.S. Department of Energy
EPC						engineering, procurement and construction
FASB						Financial Accounting Standards Board
FERC						Federal Energy Regulatory Commission
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 USD 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 index price, less a fixed liquefaction fee, shipping and other costs
LIBOR						London Interbank Offered Rate
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, 2021,~~March 31, 2022, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:

Unless the context requires otherwise, references to “Cheniere,” the “Company,” “we,” “us” and “our” refer to Cheniere Energy, Inc. and its consolidated subsidiaries, including our publicly traded subsidiary, ~~Cheniere Partners.~~CQP.

Unless the context requires otherwise, references to the “CCH Group” refer to CCH, ~~HoldCo II, CCH HoldCo I, CCH,~~ CCL and CCP, collectively.

Table of Contents

PART I. FINANCIAL INFORMATION

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(unaudited)

Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
Revenues
LNG revenues $ 2,913 $ 2,295 $ 5,912 $ 4,863
Regasification revenues 67 68 134 135
Other revenues 37 39 61 113
Total revenues 3,017 2,402 6,107 5,111
Operating costs and expenses
Cost of sales (excluding items shown separately below) 2,154 803 3,540 1,527
Operating and maintenance expense 385 355 707 671
Development expense 2 1 3 5
Selling, general and administrative expense 73 73 154 154
Depreciation and amortization expense 258 233 494 466
Impairment expense and loss (gain) on disposal of assets (1) 0 (1) 5
Total operating costs and expenses 2,871 1,465 4,897 2,828
Income from operations 146 937 1,210 2,283
Other income (expense)
Interest expense, net of capitalized interest (368) (407) (724) (819)
Loss on modification or extinguishment of debt (4) (43) (59) (44)
Interest rate derivative loss, net (2) (25) (1) (233)
Other income, net 4 5 10 14
Total other expense (370) (470) (774) (1,082)
Income (loss) before income taxes and non-controlling interest (224) 467 436 1,201
Less: income tax provision (benefit) (93) 63 (4) 194
Net income (loss) (131) 404 440 1,007
Less: net income attributable to non-controlling interest 198 207 376 435
Net income (loss) attributable to common stockholders $ (329) $ 197 $ 64 $ 572
Net income (loss) per share attributable to common stockholders—basic (1) $ (1.30) $ 0.78 $ 0.25 $ 2.27
Net income (loss) per share attributable to common stockholders—diluted (1) $ (1.30) $ 0.78 $ 0.25 $ 2.26
Weighted average number of common shares outstanding—basic 253.5 252.1 253.2 252.6
Weighted average number of common shares outstanding—diluted 253.5 252.4 254.7 253.3


	Three Months Ended March 31,
		2022		2021
Revenues
LNG revenues		$	7,340	$	2,999
Regasification revenues		68		67
Other revenues		76		24

Total revenues		7,484		3,090

Operating costs and expenses
Cost of sales (excluding items shown separately below)		7,336		1,386

Operating and maintenance expense		389		322
Development expense		5		1
Selling, general and administrative expense		96		81
Depreciation and amortization expense		271		236




Total operating costs and expenses		8,097		2,026

Income (loss) from operations		(613)		1,064

Other income (expense)
Interest expense, net of capitalized interest		(349)		(356)
Loss on modification or extinguishment of debt		(18)		(55)
Interest rate derivative gain, net		3		1
Other income, net		5		6
Total other expense		(359)		(404)

Income (loss) before income taxes and non-controlling interest		(972)		660
Less: income tax provision (benefit)		(191)		89
Net income (loss)		(781)		571
Less: net income attributable to non-controlling interest		84		178
Net income (loss) attributable to common stockholders		$	(865)	$	393

Net income (loss) per share attributable to common stockholders—basic (1)		$	(3.41)	$	1.56
Net income (loss) per share attributable to common stockholders—diluted (1)		$	(3.41)	$	1.54

Weighted average number of common shares outstanding—basic		254.0		252.9
Weighted average number of common shares outstanding—diluted		254.0		258.9

(1)Earnings per share in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

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

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (1)

(in millions, except share data)


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
ASSETS	ASSETS	(unaudited)				ASSETS	(unaudited)
Current assets	Current assets					Current assets
Cash and cash equivalents	Cash and cash equivalents	$	1,806	$	1,628	Cash and cash equivalents	$	2,487	$	1,404
Restricted cash		424		449
Accounts and other receivables, net of current expected credit losses		613		647
Restricted cash and cash equivalents						Restricted cash and cash equivalents	419		413
Trade and other receivables, net of current expected credit losses						Trade and other receivables, net of current expected credit losses	1,461		1,506

Inventory	Inventory	363		292		Inventory	571		706
Current derivative assets	Current derivative assets	178		32		Current derivative assets	215		55
Margin deposits						Margin deposits	456		765
Other current assets	Other current assets	281		121		Other current assets	96		207
Total current assets	Total current assets	3,665		3,169		Total current assets	5,705		5,056

Property, plant and equipment, net of accumulated depreciation	Property, plant and equipment, net of accumulated depreciation	30,288		30,421		Property, plant and equipment, net of accumulated depreciation	30,314		30,288
Operating lease assets	Operating lease assets	1,698		759		Operating lease assets	1,975		2,102

Derivative assets	Derivative assets	96		376		Derivative assets	43		69
Goodwill	Goodwill	77		77		Goodwill	77		77
Deferred tax assets	Deferred tax assets	497		489		Deferred tax assets	1,450		1,204
Other non-current assets, net	Other non-current assets, net	431		406		Other non-current assets, net	491		462
Total assets	Total assets	$	36,752	$	35,697	Total assets	$	40,055	$	39,258

LIABILITIES AND STOCKHOLDERS’ EQUITY
LIABILITIES AND STOCKHOLDERS' DEFICIT						LIABILITIES AND STOCKHOLDERS' DEFICIT
Current liabilities	Current liabilities					Current liabilities
Accounts payable	Accounts payable	$	83	$	35	Accounts payable	$	167	$	155
Accrued liabilities	Accrued liabilities	1,197		1,175		Accrued liabilities	1,963		2,299

Current debt, net of discount and debt issuance costs	Current debt, net of discount and debt issuance costs	949		372		Current debt, net of discount and debt issuance costs	62		366
Deferred revenue	Deferred revenue	105		138		Deferred revenue	120		155
Current operating lease liabilities	Current operating lease liabilities	365		161		Current operating lease liabilities	527		535
Current derivative liabilities	Current derivative liabilities	822		313		Current derivative liabilities	1,746		1,089
Other current liabilities	Other current liabilities	5		2		Other current liabilities	20		94
Total current liabilities	Total current liabilities	3,526		2,196		Total current liabilities	4,605		4,693

Long-term debt, net of premium, discount and debt issuance costs	Long-term debt, net of premium, discount and debt issuance costs	29,327		30,471		Long-term debt, net of premium, discount and debt issuance costs	28,907		29,449
Operating lease liabilities	Operating lease liabilities	1,332		597		Operating lease liabilities	1,423		1,541
Finance lease liabilities	Finance lease liabilities	57		57		Finance lease liabilities	57		57

Derivative liabilities	Derivative liabilities	145		151		Derivative liabilities	6,256		3,501
Other non-current liabilities	Other non-current liabilities	8		7		Other non-current liabilities	66		50

Stockholders’ equity
Preferred stock, $0.0001 par value, 5.0 million shares authorized, NaN issued		0		0
Common stock, $0.003 par value, 480.0 million shares authorized; 275.0 million shares and 273.1 million shares issued at June 30, 2021 and December 31, 2020, respectively		1		1
Stockholders' deficit						Stockholders' deficit
Preferred stock: $0.0001 par value, 5.0 million shares authorized, none issued						Preferred stock: $0.0001 par value, 5.0 million shares authorized, none issued	—		—
Common stock: $0.003 par value, 480.0 million shares authorized; 276.5 million shares and 275.2 million shares issued at March 31, 2022 and December 31, 2021, respectively						Common stock: $0.003 par value, 480.0 million shares authorized; 276.5 million shares and 275.2 million shares issued at March 31, 2022 and December 31, 2021, respectively	1		1

Treasury stock: 21.4 million shares and 20.8 million shares at June 30, 2021 and December 31, 2020, respectively, at cost		(915)		(872)
Treasury stock: 22.1 million shares and 21.6 million shares at March 31, 2022 and December 31, 2021, respectively, at cost						Treasury stock: 22.1 million shares and 21.6 million shares at March 31, 2022 and December 31, 2021, respectively, at cost	(988)		(928)
Additional paid-in-capital	Additional paid-in-capital	4,337		4,273		Additional paid-in-capital	4,244		4,377
Accumulated deficit	Accumulated deficit	(3,529)		(3,593)		Accumulated deficit	(6,967)		(6,021)
Total stockholders' deficit	Total stockholders' deficit	(106)		(191)		Total stockholders' deficit	(3,710)		(2,571)
Non-controlling interest	Non-controlling interest	2,463		2,409		Non-controlling interest	2,451		2,538
Total equity		2,357		2,218
Total liabilities and stockholders’ equity		$	36,752	$	35,697
Total deficit						Total deficit	(1,259)		(33)
Total liabilities and stockholders' deficit						Total liabilities and stockholders' deficit	$	40,055	$	39,258

(1)Amounts presented include balances held by our consolidated variable interest entity (“VIE”), ~~Cheniere Partners,~~CQP, as further discussed in Note 8— 7 —Non-controlling Interest and Variable Interest Entity. As of ~~June 30, 2021,~~March 31, 2022, total assets and liabilities of ~~Cheniere Partners,~~CQP, which are included in our Consolidated Balance Sheets, were ~~$18.9~~$19.2 billion and ~~$18.5~~$21.8 billion, respectively, including $1.2 billion of cash and cash equivalents and $0.1 billion of restricted ~~cash.~~cash and cash equivalents.

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

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (DEFICIT)

(in millions)

(unaudited)

Three and Six Months Ended June 30, 2021
Total Stockholders’ Equity
Common Stock Treasury Stock Additional Paid-in Capital Accumulated Deficit Non-controlling Interest Total
Equity
Shares Par Value Amount Shares Amount
Balance at December 31, 2020 252.3 $ 1 20.8 $ (872) $ 4,273 $ (3,593) $ 2,409 $ 2,218
Vesting of restricted stock units and performance stock units 1.8 0 0 0 0 0 0 0
Share-based compensation — 0 — 0 33 0 0 33
Issued shares withheld from employees related to share-based compensation, at cost (0.6) 0 0.6 (42) 0 0 0 (42)
Net income attributable to non-controlling interest — 0 — 0 0 0 178 178
Distributions to non-controlling interest — 0 — 0 0 0 (160) (160)
Net income — 0 — 0 0 393 0 393
Balance at March 31, 2021 253.5 1 21.4 (914) 4,306 (3,200) 2,427 2,620
Vesting of restricted stock units and performance stock units 0.1 0 0 0 0 0 0 0
Share-based compensation — 0 — 0 31 0 0 31
Issued shares withheld from employees related to share-based compensation, at cost 0 0 0 (1) 0 0 0 (1)
Net income attributable to non-controlling interest — 0 — 0 0 0 198 198
Distributions to non-controlling interest — 0 — 0 0 0 (162) (162)
Net loss — 0 — 0 0 (329) 0 (329)
Balance at June 30, 2021 253.6 $ 1 21.4 $ (915) $ 4,337 $ (3,529) $ 2,463 $ 2,357


Three Months Ended March 31, 2022
	Total Stockholders’ Deficit
	Common Stock			Treasury Stock			Additional Paid-in Capital		Accumulated Deficit		Non-controlling Interest		Total Deficit
	Shares	Par Value Amount		Shares	Amount






















Balance at December 31, 2021	253.6	$	1	21.6	$	(928)	$	4,377	$	(6,021)	$	2,538	$	(33)


















Vesting of share-based compensation awards	1.3	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		38		—		—		38
Issued shares withheld from employees related to share-based compensation, at cost	(0.3)	—		0.3	(35)		(18)		—		—		(53)
Shares repurchased, at cost	(0.2)	—		0.2	(25)		—		—		—		(25)
Adoption of ASU 2020-06, net of tax (see Note 1)	—	—		—	—		(153)		4		—		(149)
Net income attributable to non-controlling interest	—	—		—	—		—		—		84		84

Distributions to non-controlling interest	—	—		—	—		—		—		(171)		(171)
Dividends declared ($0.33 per common share)	—	—		—	—		—		(85)		—		(85)
Net loss	—	—		—	—		—		(865)		—		(865)
Balance at March 31, 2022	254.4	$	1	22.1	$	(988)	$	4,244	$	(6,967)	$	2,451	$	(1,259)

Three and Six Months Ended June 30, 2020
Total Stockholders’ Equity
Common Stock Treasury Stock Additional Paid-in Capital Accumulated Deficit Non-controlling Interest Total
Equity
Shares Par Value Amount Shares Amount
Balance at December 31, 2019 253.6 $ 1 17.1 $ (674) $ 4,167 $ (3,508) $ 2,449 $ 2,435
Vesting of restricted stock units and performance stock units 2.1 0 0 0 0 0 0 0
Share-based compensation — 0 — 0 29 0 0 29
Issued shares withheld from employees related to share-based compensation, at cost (0.7) 0 0.7 (39) 0 0 0 (39)
Shares repurchased, at cost (2.9) 0 2.9 (155) 0 0 0 (155)
Net income attributable to non-controlling interest — 0 — 0 0 0 228 228
Distributions to non-controlling interest — 0 — 0 0 0 (154) (154)
Net income — 0 — 0 0 375 0 375
Balance at March 31, 2020 252.1 1 20.7 (868) 4,196 (3,133) 2,523 2,719
Vesting of restricted stock units and performance stock units 0.1 0 0 0 0 0 0 0
Share-based compensation — 0 — 0 31 0 0 31
Issued shares withheld from employees related to share-based compensation, at cost 0 0 0 (2) 0 0 0 (2)
Net income attributable to non-controlling interest — 0 — 0 0 0 207 207
Distributions and dividends to non-controlling interest — 0 — 0 0 0 (156) (156)
Net income — 0 — 0 0 197 0 197
Balance at June 30, 2020 252.2 $ 1 20.7 $ (870) $ 4,227 $ (2,936) $ 2,574 $ 2,996


Three Months Ended March 31, 2021
	Total Stockholders’ Equity
	Common Stock			Treasury Stock			Additional Paid-in Capital		Accumulated Deficit		Non-controlling Interest		Total Equity
	Shares	Par Value Amount		Shares	Amount
Balance at December 31, 2020	252.3	$	1	20.8	$	(872)	$	4,273	$	(3,593)	$	2,409	$	2,218
Vesting of share-based compensation awards	1.8	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		33		—		—		33
Issued shares withheld from employees related to share-based compensation, at cost	(0.6)	—		0.6	(42)		—		—		—		(42)
Net income attributable to non-controlling interest	—	—		—	—		—		—		178		178
Distributions to non-controlling interest	—	—		—	—		—		—		(160)		(160)
Net income	—	—		—	—		—		393		—		393
Balance at March 31, 2021	253.5	$	1	21.4	$	(914)	$	4,306	$	(3,200)	$	2,427	$	2,620

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

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)

Six Months Ended June 30,
2021 2020
Cash flows from operating activities
Net income $ 440 $ 1,007
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense 494 466
Share-based compensation expense 63 57
Non-cash interest expense 14 34
Amortization of debt issuance costs, premium and discount 40 70
Reduction of right-of-use assets 172 166
Loss on modification or extinguishment of debt 59 44
Total losses (gains) on derivatives, net 748 (361)
Net cash provided by (used for) settlement of derivative instruments (111) 117
Impairment expense and loss (gain) on disposal of assets (1) 5
Impairment expense and loss (income) on equity method investments (8) 1
Deferred taxes (7) 192
Repayment of paid-in-kind interest related to repurchase of convertible notes (190) 0
Changes in operating assets and liabilities:
Accounts and other receivables, net of current expected credit losses 33 (155)
Inventory (66) 104
Other current assets (163) (37)
Accounts payable and accrued liabilities 88 (369)
Deferred revenue (33) (138)
Operating lease liabilities (173) (145)
Other, net (26) (30)
Net cash provided by operating activities 1,373 1,028
Cash flows from investing activities
Property, plant and equipment (440) (983)
Proceeds from sale of fixed assets 68 0
Investment in equity method investment 0 (100)
Other (11) (7)
Net cash used in investing activities (383) (1,090)
Cash flows from financing activities
Proceeds from issuances of debt 2,184 2,597
Repayments of debt (2,603) (2,380)
Debt issuance and other financing costs (20) (59)
Debt modification or extinguishment costs (41) (40)
Distributions to non-controlling interest (322) (310)
Payments related to tax withholdings for share-based compensation (43) (41)
Repurchase of common stock 0 (155)
Other 8 0
Net cash used in financing activities (837) (388)
Net increase (decrease) in cash, cash equivalents and restricted cash 153 (450)
Cash, cash equivalents and restricted cash—beginning of period 2,077 2,994
Cash, cash equivalents and restricted cash—end of period $ 2,230 $ 2,544


	Three Months Ended March 31,
	March 31,
	2022		2021
Cash flows from operating activities
Net income (loss)	$	(781)	$	571
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	271		236
Share-based compensation expense	43		32
Non-cash interest expense	2		8
Amortization of debt issuance costs, premium and discount	15		20
Reduction of right-of-use assets	134		85
Loss on modification or extinguishment of debt	18		55
Total losses on derivative instruments, net	3,592		74
Net cash provided by (used for) settlement of derivative instruments	(314)		5

Impairment expense and loss (income) on equity method investments	(5)		(7)
Deferred taxes	(206)		87
Repayment of paid-in-kind interest related to repurchase of convertible notes	(13)		—
Other	—		1
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	(16)		(3)

Inventory	133		(16)
Margin deposits	309		(17)
Other current assets	99		16
Accounts payable and accrued liabilities	(386)		52

Deferred revenue	(24)		(36)
Operating lease liabilities	(134)		(86)
Finance lease liabilities	1		—
Other, net	(83)		(11)
Net cash provided by operating activities	2,655		1,066

Cash flows from investing activities
Property, plant and equipment	(178)		(190)


Other	—		(10)
Net cash used in investing activities	(178)		(200)

Cash flows from financing activities
Proceeds from issuances of debt	575		1,800
Redemptions and repayments of debt	(1,615)		(2,088)
Debt issuance and other financing costs	—		(19)
Debt modification or extinguishment costs	(13)		(40)

Distributions to non-controlling interest	(171)		(160)
Payments related to tax withholdings for share-based compensation	(53)		(42)
Repurchase of common stock	(25)		—
Cash dividends to shareholders	(86)		—
Other	—		4
Net cash used in financing activities	(1,388)		(545)

Net increase in cash, cash equivalents and restricted cash and cash equivalents	1,089		321
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	1,817		2,077
Cash, cash equivalents and restricted cash and cash equivalents—end of period	$	2,906	$	2,398

Balances per Consolidated Balance ~~Sheets:~~Sheet:


	~~June 30,~~March 31,
	~~2021~~2022
Cash and cash equivalents	$	~~1,806~~2,487
Restricted cash and cash equivalents	~~424~~419

Total cash, cash equivalents and restricted cash and cash equivalents	$	~~2,230~~2,906

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

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We operate 2 natural gas liquefaction and export facilities located in Cameron Parish, Louisiana at Sabine Pass and near Corpus Christi, Texas (respectively, the “Sabine Pass LNG Terminal” and “Corpus Christi LNG Terminal”).

~~Cheniere Partners~~CQP owns the Sabine Pass LNG Terminal ~~located in Cameron Parish, Louisiana,~~ which has natural gas liquefaction facilities consisting of 56 operational ~~natural gas liquefaction~~ Trains, ~~and 1 additional~~with Train ~~under construction that is expected to be substantially completed in the first half of~~6 achieving substantial completion on February 4, 2022, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include 5 LNG storage tanks, vaporizers and 2 marine berths, with an additional marine berth that is under construction. ~~Cheniere Partners~~CQP also owns a 94-mile pipeline that interconnects the Sabine Pass LNG Terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) through its subsidiary, CTPL. As of ~~June 30, 2021,~~March 31, 2022, we owned 100% of the general partner interest and a 48.6% ~~of the~~ limited partner interest in ~~Cheniere Partners.~~CQP.

The Corpus Christi LNG Terminal ~~is located near Corpus Christi, Texas. We~~ currently ~~operate~~has 3 Trains, for a total production capacity of approximately 15 mtpa of LNG. We also own a ~~23-mile~~21.5-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Trains, the “CCL Project”) through our subsidiary CCP, as part of the CCH Group. The CCL Project also ~~contains~~includes 3 LNG storage tanks and 2 marine berths.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG Terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) through our subsidiary CCL Stage III, for up to 7 midscale Trains with an expected total production capacity of ~~approximately~~over 10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and operate the expansion project. In March 2022, CCL Stage III issued limited notice to proceed to Bechtel Oil, Gas and Chemicals, Inc. to commence early engineering, procurement and site works.

~~We remain focused on 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 the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) as a result of debottlenecking and other optimization projects. We hold significant land positions at both the Sabine Pass LNG Terminal and the Corpus Christi LNG Terminal which provide opportunity for further liquefaction capacity expansion. The development of these sites 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 final investment decision (“FID”).

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, ~~2020~~202 1. Reclassifications that are not material to our Consolidated Financial Statements, if any, are made to prior period financial information to conform to the current year presentation.

Results of operations for the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, ~~2021.~~2022.

Recent Accounting Standards

ASU 2020-06

In August 2020, the ~~Financial Accounting Standards Board (“FASB”)~~FASB issued ~~Accounting Standards Update (“ASU”)~~ASU 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. This guidance simplifies the accounting for convertible instruments primarily by eliminating the existing cash conversion and beneficial conversion models within Subtopic 470-20, which will result in fewer embedded conversion options being accounted for separately from the debt host. The guidance also amends and simplifies the calculation of earnings per share relating to convertible instruments. This guidance is effective for annual periods beginning after December 15, 2021, including interim periods within that reporting period, with earlier adoption permitted for fiscal years

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

beginning after December 15, 2020, including interim periods within that reporting period, using either a full or modified retrospective approach. We ~~plan to adopt~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

adopted this guidance on January 1, 2022 using the modified retrospective approach. ~~Preliminarily, we anticipate the~~The adoption of ASU 2020-06 ~~will~~ primarily ~~result~~resulted in the reclassification of the previously bifurcated equity component associated with the 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to debt as a result of the elimination of the cash conversion model. ~~We currently estimate that~~As of January 1, 2022, the reclassification resulted in: (1) a $194 million reduction of the ~~$194 million~~ equity component ~~will result~~recorded in ~~an approximate $190~~additional paid-in capital, before offsetting tax effect of $41 million, (2) a $189 million increase in the carrying value of our 2045 Cheniere Convertible Senior Notes ~~with the difference primarily impacting retained earnings as~~and (3) a $5 million decrease in accumulated deficit, before offsetting tax effect of $1 million. In December 2021, we issued a notice of redemption for all $625 million aggregate principal amount outstanding of our 2045 Cheniere Convertible Senior Notes, which were redeemed on January 1,5, 2022. ~~We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.~~ See Note ~~10—~~9 —Debt for further discussion onof the 2045 Cheniere Convertible Senior Notes.

The adoption of ASU 2020-06 also impacted the calculation of the dilutive effect of our 2045 Cheniere Convertible Senior Notes on our net loss per share for the three months ended March 31, 2022, as further discussed in Note 14—Net Income (Loss) per Share Attributable to Common Stockholders.

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 contracts expected to arise from the market transition from LIBOR to alternative reference rates. The transition period under this standard is effective March 12, 2020 and will apply through December 31, 2022.

We have interest rate swaps and various credit facilities ~~and interest rate swaps~~ indexed to LIBOR, as further described in Note 6—6 —Derivative Instruments and Note ~~10—~~9 —Debt~~. The optional expedients were available to be used upon issuance of this guidance but~~, respectively. To date, we have ~~not yet applied the guidance because we have not yet modified any~~amended certain of our ~~existing contracts for reference~~credit facilities to incorporate a fallback replacement rate ~~reform. Once we~~indexed to SOFR as a result of the expected LIBOR transition. We elected to apply ~~an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time~~ the optional expedients ~~are no longer available.~~as applicable to certain modified terms, however the impact of applying the optional expedients was not material, and we do not expect the transition to a replacement rate indexed to SOFR to have a material impact on our future cash flows. We will continue to elect to apply the optional expedients to qualifying contract modifications in the future.

NOTE 2—RESTRICTED CASH AND CASH EQUIVALENTS

Restricted cash ~~consists~~and cash equivalents consist of funds that are contractually or legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. ~~As of June 30, 2021~~Restricted cash and ~~December 31, 2020, restricted~~ cash equivalents consisted of the following (in millions):


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
Restricted cash
Restricted cash and cash equivalents						Restricted cash and cash equivalents
SPL Project	SPL Project	$	65	$	97	SPL Project	$	136	$	98

CCL Project	CCL Project	122		70		CCL Project	50		44
Cash held by our subsidiaries that is restricted to Cheniere	Cash held by our subsidiaries that is restricted to Cheniere	237		282		Cash held by our subsidiaries that is restricted to Cheniere	233		271
Total restricted cash		$	424	$	449
Total restricted cash and cash equivalents						Total restricted cash and cash equivalents	$	419	$	413

Pursuant to the accounts agreements entered into with the collateral trustees for the benefit of SPL’s debt holders and CCH’s debt holders, SPL and CCH are required to deposit all cash received into reserve accounts controlled by the collateral trustees. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Projects and other restricted payments. The majority of the cash held by our subsidiaries that is restricted to Cheniere relates to advance funding for operation and construction needs of the Liquefaction Projects.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 3—~~ACCOUNTS~~TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES

~~As of June 30, 2021 and December 31, 2020, accounts~~Trade and other receivables, net of current expected credit losses consisted of the following (in millions):


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
Trade receivables	Trade receivables					Trade receivables
SPL and CCL	SPL and CCL	$	405	$	482	SPL and CCL	$	571	$	802

Cheniere Marketing	Cheniere Marketing	123		113		Cheniere Marketing	750		640
Other accounts receivable, net of current expected credit losses		85		52

Total accounts and other receivables, net of current expected credit losses		$	613	$	647
Other receivables						Other receivables	140		64
Total trade and other receivables, net of current expected credit losses						Total trade and other receivables, net of current expected credit losses	$	1,461	$	1,506

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE 4—INVENTORY

~~As of June 30, 2021 and December 31, 2020, inventory~~Inventory consisted of the following (in millions):


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
Materials	Materials	$	162	$	150	Materials	$	178	$	174
LNG in-transit	LNG in-transit	102		88		LNG in-transit	210		312
LNG	LNG	61		27		LNG	135		153
Natural gas	Natural gas	36		26		Natural gas	44		64
Other	Other	2		1		Other	4		3
Total inventory	Total inventory	$	363	$	292	Total inventory	$	571	$	706

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

~~As of June 30, 2021 and December 31, 2020, property,~~Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
LNG terminal	LNG terminal					LNG terminal
LNG terminal and interconnecting pipeline facilities	LNG terminal and interconnecting pipeline facilities	$	30,598	$	27,475	LNG terminal and interconnecting pipeline facilities	$	33,138	$	30,660
LNG site and related costs	LNG site and related costs	343		324		LNG site and related costs	442		441
LNG terminal construction-in-process	LNG terminal construction-in-process	2,650		5,378		LNG terminal construction-in-process	809		2,995
Accumulated depreciation	Accumulated depreciation	(3,413)		(2,935)		Accumulated depreciation	(4,176)		(3,912)
Total LNG terminal, net of accumulated depreciation	Total LNG terminal, net of accumulated depreciation	30,178		30,242		Total LNG terminal, net of accumulated depreciation	30,213		30,184
Fixed assets and other	Fixed assets and other					Fixed assets and other
Computer and office equipment	Computer and office equipment	27		25		Computer and office equipment	26		25
Furniture and fixtures	Furniture and fixtures	20		19		Furniture and fixtures	19		20
Computer software	Computer software	120		117		Computer software	123		120
Leasehold improvements	Leasehold improvements	45		45		Leasehold improvements	46		45
Land	Land	1		59		Land	1		1
Other	Other	20		25		Other	18		19
Accumulated depreciation	Accumulated depreciation	(175)		(164)		Accumulated depreciation	(181)		(176)
Total fixed assets and other, net of accumulated depreciation	Total fixed assets and other, net of accumulated depreciation	58		126		Total fixed assets and other, net of accumulated depreciation	52		54
Assets under finance lease	Assets under finance lease					Assets under finance lease
Tug vessels	Tug vessels	60		60		Tug vessels	60		60
Accumulated depreciation	Accumulated depreciation	(8)		(7)		Accumulated depreciation	(11)		(10)
Total assets under finance lease, net of accumulated depreciation	Total assets under finance lease, net of accumulated depreciation	52		53		Total assets under finance lease, net of accumulated depreciation	49		50
Property, plant and equipment, net of accumulated depreciation	Property, plant and equipment, net of accumulated depreciation	$	30,288	$	30,421	Property, plant and equipment, net of accumulated depreciation	$	30,314	$	30,288

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows depreciation expense and offsets to LNG terminal costs ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
Depreciation expense	Depreciation expense	$	258	$	231	$	492	$	463	Depreciation expense		$	270	$	234
Offsets to LNG terminal costs (1)	Offsets to LNG terminal costs (1)	36		0		227		0		Offsets to LNG terminal costs (1)		204		191

(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 Projects during the testing phase for its construction.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE 6—DERIVATIVE INSTRUMENTS

We have entered into the following derivative instruments that are reported at fair value:

•interest rate swaps (“~~CCH~~ Interest Rate Derivatives”) to hedge the exposure to volatility in a portion of the floating-rate interest payments on CCH’s amended and restated term loan credit facility (the “CCH Credit Facility”) and previously, to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”);

•commodity derivatives consisting of natural gas supply contracts, including those under our IPM agreements, for the commissioning and operation of the Liquefaction Projects and potential future development of Corpus Christi Stage 3 (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”);

•physical derivatives consisting of liquified natural gas contracts in which we have contractual net settlement (“Physical LNG Trading Derivatives”) and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”); and

•foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with cash flows denominated in currencies other than United States dollar (“FX Derivatives”), associated with both LNG Trading Derivatives and operations in countries outside of the United States.

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 it is 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 ~~as of June 30, 2021 and December 31, 2020~~ (in millions):

Fair Value Measurements as of
June 30, 2021 December 31, 2020
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
CCH Interest Rate Derivatives liability $ 0 $ (91) $ 0 $ (91) $ 0 $ (140) $ 0 $ (140)
Liquefaction Supply Derivatives asset (liability) (7) 4 (194) (197) 5 (6) 241 240
LNG Trading Derivatives asset (liability) 20 (226) (195) (401) (3) (131) 0 (134)
FX Derivatives liability 0 (4) 0 (4) 0 (22) 0 (22)


	Fair Value Measurements as of
	March 31, 2022								December 31, 2021
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Interest Rate Derivatives liability	$	—	$	(12)	$	—	$	(12)	$	—	$	(40)	$	—	$	(40)

Liquefaction Supply Derivatives asset (liability)	(75)		9		(7,423)		(7,489)		7		(9)		(4,036)		(4,038)
LNG Trading Derivatives liability	(8)		(260)		—		(268)		(22)		(378)		—		(400)
FX Derivatives asset	—		25		—		25		—		12		—		12

We value our Interest Rate Derivatives using an income-based approach utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our LNG Trading Derivatives and 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. We value our FX Derivatives with a market approach using observable FX rates and other relevant data.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The fair value of our Physical Liquefaction Supply Derivatives and LNG Trading Derivatives are 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, ~~evaluating~~but not limited to, evaluation of whether the respective market ~~is available~~exists from the perspective of market participants as ~~pipeline~~ infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of June 30, 2021 and December 31, 2020, some of our Physical Liquefaction

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

~~Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow.~~

We include our Physical LNG Trading Derivatives and 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 ~~volatility~~ and ~~contract duration.~~volatility.

The Level 3 fair value measurements of our Physical LNG Trading Derivatives and the 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 ~~and Physical LNG Trading Derivatives~~ as of ~~June 30, 2021:~~March 31, 2022:

Net Fair Value Liability
(in millions)

Valuation Approach

Significant Unobservable Input

Range of Significant Unobservable Inputs / Weighted Average (1)

Physical Liquefaction Supply Derivatives

$~~(194)~~(7,423)

Market approach incorporating present value techniques

Henry Hub basis spread

$~~(0.573)~~(1.578) - ~~$0.385~~$0.215 / ~~$(0.009)~~$(0.094)

Option pricing model

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

~~137%~~101% - ~~297%~~533% / ~~175%~~190%

~~Physical LNG Trading Derivatives~~

~~$(195)~~

~~Market approach incorporating present value techniques~~

~~International LNG pricing spread, relative to Henry Hub or TTF, as applicable (2)~~

~~$(3.108) - $7.078 / $5.161~~

(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 LNG Trading Derivatives and our Physical Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of our Level 3 Physical LNG Trading Derivatives and Physical Liquefaction Supply Derivatives ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):

Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
Balance, beginning of period $ 131 $ 674 $ 241 $ 138
Realized and mark-to-market gains (losses):
Included in cost of sales (464) (84) (471) 452
Purchases and settlements:
Purchases (58) (4) (187) (3)
Settlements 2 1 28 (1)
Transfers into Level 3, net (1) 0 3 0 4
Balance, end of period $ (389) $ 590 $ (389) $ 590
Change in unrealized gains (losses) relating to instruments still held at end of period $ (464) $ (84) $ (471) $ 452

~~(1)Transferred into Level 3 as a result of unobservable market for the underlying natural gas purchase agreements.~~


	Three Months Ended March 31,
		2022		2021
Balance, beginning of period		$	(4,036)	$	241
Realized and mark-to-market losses:
Included in cost of sales		(3,540)		(129)

Purchases and settlements:
Purchases		(3)		(14)
Settlements		156		33

Balance, end of period		$	(7,423)	$	131
Change in unrealized losses relating to instruments still held at end of period		$	(3,540)	$	(129)

~~All~~Except for Interest Rate Derivatives, 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~~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

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Interest Rate Derivatives

CCH has entered into interest rate swaps to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility. CCH previously also had interest rate swaps to hedge against changes in interest rates that could impact the anticipated future issuance of debt. In August 2020, we settled the outstanding CCH Interest Rate Forward Start Derivatives.

As of ~~June 30, 2021,~~March 31, 2022, we had the following Interest Rate Derivatives outstanding:

Notional Amounts

~~June 30, 2021~~March 31, 2022

December 31, ~~2020~~2021

Latest Maturity Date

Weighted Average Fixed Interest Rate Paid

Variable Interest Rate Received

~~CCH~~ Interest Rate Derivatives

$~~4.6~~4.5 billion

May 31, 2022

2.30%

One-month LIBOR

The following table shows the ~~gain (loss) from changes in the fair value~~effect and ~~settlements~~location of our Interest Rate Derivatives ~~recorded in interest rate derivative loss, net~~ on our Consolidated Statements of Operations ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):

Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
CCH Interest Rate Derivatives $ (2) $ (15) $ (1) $ (138)
CCH Interest Rate Forward Start Derivatives 0 (10) 0 (95)


			Gain Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended March 31,
				2022		2021
Interest Rate Derivatives	Interest rate derivative gain, net			$	3	$	1

Commodity Derivatives

SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges, including those associated with our integrated production marketing (“IPM”) transactions, to purchase natural gas for the commissioning and operation of the Liquefaction ~~Projects and potential future development of Corpus Christi Stage 3, respectively,~~Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. The remaining minimum terms of the index-based physical natural gas supply contracts range up to approximately 1516 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.

Commencing in first quarter of 2021, we have entered into physical LNG transactions that provide for contractual net settlement. Such transactions are accounted for as LNG Trading Derivatives, and are designed to economically hedge exposure to the commodity markets in which we sell LNG. We have entered into, and may from time to time enter into, financial LNG Trading Derivatives in the form of swaps, forwards, options or futures. The terms of LNG Trading Derivatives range up to approximately two years.

The following table shows the notional amounts of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”):

June 30, 2021 December 31, 2020
Liquefaction Supply Derivatives LNG Trading Derivatives Liquefaction Supply Derivatives LNG Trading Derivatives
Notional amount, net (in TBtu) (1) 10,631 14 10,483 20

March 31, 2022

December 31, 2021

Liquefaction Supply Derivatives (1)

LNG Trading Derivatives

Liquefaction Supply Derivatives

LNG Trading Derivatives

Notional amount, net (in TBtu)

13,036

11,238

(1) ~~Includes~~Excludes notional amounts ~~for natural gas supply contracts~~associated with extension options that ~~SPL and CCL have with related parties. See~~ ~~Note 13—Related Party Transactions~~.were uncertain to be taken as of March 31, 2022.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the ~~gain (loss) from changes in the fair value, settlements~~effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):


																									Gain (Loss) Recognized in Consolidated Statements of Operations
		Consolidated Statements of Operations Location (1)		Three Months Ended June 30,						Six Months Ended June 30,						Consolidated Statements of Operations Location (1)							Three Months Ended March 31,
			2021		2020			2021			2020						Consolidated Statements of Operations Location (1)							2022			2021

LNG Trading Derivatives	LNG Trading Derivatives		LNG revenues		$	(379)		$	(34)		$	(441)		$	106					LNG Trading Derivatives		LNG revenues					$	(247)			$	(62)
LNG Trading Derivatives	LNG Trading Derivatives	Cost of sales		53			34			81			0						LNG Trading Derivatives		Cost of sales					90				28
Liquefaction Supply Derivatives (2)	Liquefaction Supply Derivatives (2)	LNG revenues		0			(13)			1			(14)					Liquefaction Supply Derivatives (2)	LNG revenues						(5)				1
Liquefaction Supply Derivatives (2)	Liquefaction Supply Derivatives (2)	Cost of sales		(341)			(62)			(404)			475					Liquefaction Supply Derivatives (2)	Cost of sales						(3,461)				(63)

(1)Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

(2)Does not include the realized value associated with derivative instruments that settle through physical delivery.

FX Derivatives

Cheniere Marketing has entered into FX Derivatives to protect against the volatility in future cash flows attributable to changes in international currency exchange rates. The FX Derivatives economically hedge the foreign currency exposure arising from cash flows expended for both physical and financial LNG transactions that are denominated in a currency other than the United States dollar. The terms of FX Derivatives range up to approximately one year.

The total notional amount of our FX Derivatives was ~~$267~~$920 million and ~~$786~~$762 million as of ~~June 30, 2021~~March 31, 2022 and December 31, ~~2020,~~2021, respectively.

The following table shows the ~~gain (loss) from changes in the fair value, settlements~~effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):

Consolidated Statements of Operations Location Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
FX Derivatives LNG revenues $ (5) $ 2 $ 16 $ 27


			Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended March 31,
				2022		2021
FX Derivatives	LNG revenues			$	28	$	21

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 derivative instruments on our Consolidated Balance Sheets (in millions):


		June 30, 2021
		CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives			Total
Consolidated Balance Sheets Location
Current derivative assets		$	0	$	53	$	119	$	6		$	178
Derivative assets		0		96		0		0			96
Total derivative assets		0		149		119		6			274

Current derivative liabilities		(91)		(201)		(520)		(10)			(822)
Derivative liabilities		0		(145)		0		0			(145)
Total derivative liabilities		(91)		(346)		(520)		(10)			(967)

Derivative liability, net		$	(91)	$	(197)	$	(401)	$	(4)		$	(693)

		December 31, 2020								March 31, 2022
		CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives			Total			Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location	Consolidated Balance Sheets Location												Consolidated Balance Sheets Location
Current derivative assets	Current derivative assets	$	0	$	27	$	0	$	5		$	32	Current derivative assets	$	—	$	45	$	145	$	25	$	215
Derivative assets	Derivative assets	0		376		0		0			376		Derivative assets	—		43		—		—		43
Total derivative assets	Total derivative assets	0		403		0		5			408		Total derivative assets	—		88		145		25		258

Current derivative liabilities	Current derivative liabilities	(100)		(54)		(134)		(25)			(313)		Current derivative liabilities	(12)		(1,321)		(413)		—		(1,746)
Derivative liabilities	Derivative liabilities	(40)		(109)		0		(2)			(151)		Derivative liabilities	—		(6,256)		—		—		(6,256)
Total derivative liabilities	Total derivative liabilities	(140)		(163)		(134)		(27)			(464)		Total derivative liabilities	(12)		(7,577)		(413)		—		(8,002)

Derivative asset (liability), net	Derivative asset (liability), net	$	(140)	$	240	$	(134)	$	(22)		$	(56)	Derivative asset (liability), net	$	(12)	$	(7,489)	$	(268)	$	25	$	(7,744)

														December 31, 2021
														Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location													Consolidated Balance Sheets Location
Current derivative assets													Current derivative assets	$	—	$	38	$	2	$	15	$	55
Derivative assets													Derivative assets	—		69		—		—		69
Total derivative assets													Total derivative assets	—		107		2		15		124

Current derivative liabilities													Current derivative liabilities	(40)		(644)		(402)		(3)		(1,089)
Derivative liabilities													Derivative liabilities	—		(3,501)		—		—		(3,501)
Total derivative liabilities													Total derivative liabilities	(40)		(4,145)		(402)		(3)		(4,590)

Derivative asset (liability), net													Derivative asset (liability), net	$	(40)	$	(4,038)	$	(400)	$	12	$	(4,466)

(1)Does not include collateral posted with counterparties by us of ~~$22~~$96 million and $9$20 million as of March 31, 2022 and December 31, 2021, respectively, which are included in ~~other current assets~~margin deposits in our Consolidated Balance ~~Sheets as of June 30, 2021 and December 31, 2020, respectively. Includes derivative assets for natural gas supply contracts that SPL and CCL have with related parties. See~~ ~~Note 13—Related Party Transactions~~.Sheets.

(2)Does not include collateral posted with counterparties by us of $1$360 million and $7$745 million, as of March 31, 2022 and December 31, 2021, respectively, which are included in ~~other current assets~~margin deposits in our Consolidated Balance ~~Sheets as of June 30, 2021 and December 31, 2020, respectively.~~Sheets.

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Consolidated Balance Sheets Presentation

~~Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above.~~ The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions): for our derivative instruments that are presented on a net basis on our Consolidated Balance Sheets:


		CCH Interest Rate Derivatives		Liquefaction Supply Derivatives			LNG Trading Derivatives		FX Derivatives					Liquefaction Supply Derivatives		LNG Trading Derivatives		FX Derivatives
						FX Derivatives						Liquefaction Supply Derivatives	FX Derivatives
As of June 30, 2021
As of March 31, 2022											As of March 31, 2022
Gross assets	Gross assets	$	0	$	203		$	131	$	9	Gross assets			$	113	$	198	$	62
Offsetting amounts	Offsetting amounts	0		(54)			(12)		(3)		Offsetting amounts			(25)		(53)		(37)
Net assets	Net assets	$	0	$	149		$	119	$	6	Net assets			$	88	$	145	$	25

Gross liabilities	Gross liabilities	$	(91)	$	(401)		$	(614)	$	(37)	Gross liabilities			$	(8,072)	$	(419)	$	—
Offsetting amounts	Offsetting amounts	0		55			94		27		Offsetting amounts			495		6		—
Net liabilities	Net liabilities	$	(91)	$	(346)		$	(520)	$	(10)	Net liabilities			$	(7,577)	$	(413)	$	—

As of December 31, 2020
As of December 31, 2021											As of December 31, 2021
Gross assets	Gross assets	$	0	$	452		$	0	$	6	Gross assets			$	155	$	10	$	48
Offsetting amounts	Offsetting amounts	0		(49)			0		(1)		Offsetting amounts			(48)		(8)		(33)
Net assets	Net assets	$	0	$	403		$	0	$	5	Net assets			$	107	$	2	$	15

Gross liabilities	Gross liabilities	$	(140)	$	(184)		$	(163)	$	(62)	Gross liabilities			$	(4,382)	$	(551)	$	(10)
Offsetting amounts	Offsetting amounts	0		21			29		35		Offsetting amounts			237		149		7
Net liabilities	Net liabilities	$	(140)	$	(163)		$	(134)	$	(27)	Net liabilities			$	(4,145)	$	(402)	$	(3)

NOTE 7—~~OTHER NON-CURRENT ASSETS, NET~~

~~As of June 30, 2021 and December 31, 2020, other non-current assets, net consisted of the following (in millions):~~

June 30, December 31,
2021 2020
Contract assets, net of current expected credit losses $ 105 $ 80
Advances made to municipalities for water system enhancements 82 84
Equity method investments 88 81
Advances and other asset conveyances to third parties to support LNG terminals 69 60
Debt issuance costs and debt discount, net of accumulated amortization 30 42
Advances made under EPC and non-EPC contracts 2 9
Advance tax-related payments and receivables 18 20
Other 37 30
Total other non-current assets, net $ 431 $ 406

~~Equity Method Investments~~

As of June 30, 2021, our equity method investment consists of our interest in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“Midship Pipeline”). Midship Pipeline is currently operating an approximately 200-mile natural gas pipeline project (the “Midship Project”) that connects production in the Anadarko Basin to Gulf Coast markets. The Midship Project commenced operations in April 2020.

~~Our investment in Midship Holdings, net of impairment losses, was $88 million and $80 million as of June 30, 2021 and December 31, 2020, respectively.~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

~~NOTE 8—~~NON-CONTROLLING INTEREST AND VARIABLE INTEREST ENTITY

We own a 48.6% limited partner interest in ~~Cheniere Partners~~CQP in the form of 239.9 million common units, with the remaining non-controlling limited partner interest held by ~~The~~ Blackstone ~~Group~~ Inc., Brookfield Asset Management Inc. and the public. We also own 100% of the general partner interest and the incentive distribution rights in ~~Cheniere Partners. Cheniere Partners~~CQP. CQP is accounted for as a consolidated VIE. ~~See~~ ~~Note 9—Non-Controlling Interest and Variable Interest Entity~~ ~~of our Notes to Consolidated Financial Statements in our~~ ~~annual report on Form 10-K for the fiscal year ended December 31, 2020~~ ~~for further information.~~

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table presents the summarized assets and liabilities (in millions) of ~~Cheniere Partners,~~CQP, our consolidated VIE, which are included in our Consolidated Balance ~~Sheets as of June 30, 2021 and December 31, 2020.~~Sheets. The assets in the table below may only be used to settle obligations of ~~Cheniere Partners.~~CQP. In addition, there is no recourse to us for the consolidated VIE’s liabilities. The assets and liabilities in the table below include ~~third-party~~third party assets and liabilities of ~~Cheniere Partners~~CQP only and exclude intercompany balances that eliminate in consolidation.


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
ASSETS	ASSETS					ASSETS
Current assets	Current assets					Current assets
Cash and cash equivalents	Cash and cash equivalents	$	1,239	$	1,210	Cash and cash equivalents	$	1,156	$	876
Restricted cash		65		97
Accounts and other receivables, net of current expected credit losses		285		318
Restricted cash and cash equivalents						Restricted cash and cash equivalents	136		98
Trade and other receivables, net of current expected credit losses						Trade and other receivables, net of current expected credit losses	434		580
Other current assets	Other current assets	236		182		Other current assets	266		285
Total current assets	Total current assets	1,825		1,807		Total current assets	1,992		1,839

Property, plant and equipment, net of accumulated depreciation	Property, plant and equipment, net of accumulated depreciation	16,789		16,723		Property, plant and equipment, net of accumulated depreciation	16,915		16,830
Other non-current assets, net	Other non-current assets, net	289		287		Other non-current assets, net	309		316

Total assets	Total assets	$	18,903	$	18,817	Total assets	$	19,216	$	18,985

LIABILITIES	LIABILITIES					LIABILITIES
Current liabilities	Current liabilities					Current liabilities

Accrued liabilities	Accrued liabilities	$	649	$	658	Accrued liabilities	$	1,164	$	1,077
Current debt, net of premium, discount and debt issuance costs		654		0

Other current liabilities	Other current liabilities	154		171		Other current liabilities	404		200

Total current liabilities	Total current liabilities	1,457		829		Total current liabilities	1,568		1,277

Long-term debt, net of premium, discount and debt issuance costs	Long-term debt, net of premium, discount and debt issuance costs	16,935		17,580		Long-term debt, net of premium, discount and debt issuance costs	17,184		17,177

Other non-current liabilities	Other non-current liabilities	95		126		Other non-current liabilities	3,086		100
Total liabilities	Total liabilities	$	18,487	$	18,535	Total liabilities	$	21,838	$	18,554

NOTE 9—8—ACCRUED LIABILITIES

~~As of June 30, 2021 and December 31, 2020, accrued~~Accrued liabilities consisted of the following (in millions):


		June 30,		December 31,			March 31,		December 31,
		2021		2020			2022		2021
Accrued natural gas purchases						Accrued natural gas purchases	$	1,162	$	1,323
Accrued derivative settlements						Accrued derivative settlements	35		329
Interest costs and related debt fees	Interest costs and related debt fees	$	236	$	245	Interest costs and related debt fees	367		214
Accrued natural gas purchases		559		576
LNG terminals and related pipeline costs	LNG terminals and related pipeline costs	169		147		LNG terminals and related pipeline costs	281		144
Compensation and benefits	Compensation and benefits	69		123		Compensation and benefits	46		180
Accrued LNG inventory	Accrued LNG inventory	49		4		Accrued LNG inventory	7		34

Other accrued liabilities	Other accrued liabilities	115		80		Other accrued liabilities	65		75
Total accrued liabilities	Total accrued liabilities	$	1,197	$	1,175	Total accrued liabilities	$	1,963	$	2,299

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE ~~10—~~9—DEBT

~~As of June 30, 2021 and December 31, 2020, our~~Our debt consisted of the following (in millions):

June 30, December 31,
2021 2020
Long-term debt:
SPL — 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 SPL Working Capital Facility”)
$ 12,994 $ 13,650
Cheniere Partners — 4.000% to 5.625% senior notes due between October 2025 and March 2031 and credit facilities (“2019 CQP Credit Facilities”)
4,100 4,100
CCH — 3.52% to 7.000% senior secured notes due between June 2024 and December 2039 and CCH Credit Facility
10,216 10,217
Cheniere — 4.625% senior secured notes due October 2028 (the “2028 Cheniere Senior Notes”), convertible notes, revolving credit facility (“Cheniere Revolving Credit Facility”) and term loan facility (“Cheniere Term Loan Facility”)
2,625 3,145
Unamortized premium, discount and debt issuance costs, net of accumulated amortization (608) (641)
Total long-term debt, net of premium, discount and debt issuance costs 29,327 30,471
Current debt:
SPL — current portion of 6.25% senior secured notes due March 2022 (“2022 SPL Senior Notes”) (1)
656 0
CCH — $1.2 billion CCH working capital facility (“CCH Working Capital Facility”) and current portion of CCH Credit Facility
132 271
Cheniere Marketing — trade finance facilities and letter of credit facility
30 0
Cheniere — current portion of the 4.875% convertible unsecured notes due May 2021 (“2021 Cheniere Convertible Notes”) and Cheniere Revolving Credit Facility (2)
134 104
Unamortized discount and debt issuance costs, net of accumulated amortization (3) (3)
Total current debt, net of discount and debt issuance costs 949 372
Total debt, net of premium, discount and debt issuance costs $ 30,276 $ 30,843



	March 31,		December 31,
	2022		2021
SPL:
Senior Secured Notes:

5.625% due 2023	$	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
$1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 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
CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”)	—		—
Total debt - CQP	4,200		4,200

CCH:
Senior Secured Notes:
7.000% due 2024	1,250		1,250
5.875% due 2025	1,500		1,500
5.125% due 2027	1,500		1,500
3.700% due 2029	1,500		1,500
3.72% weighted average rate due 2039	2,721		2,721
Total CCH Senior Secured Notes	8,471		8,471
CCH Credit Facility (1)	1,439		1,728
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) (2)	—		250
Total debt - CCH	9,910		10,449

Cheniere:
4.625% Senior Secured Notes due 2028	2,000		2,000

2045 Cheniere Convertible Senior Notes (3)	—		625
$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”)	—		—

Total debt - Cheniere	2,000		2,625

Cheniere Marketing: trade finance facilities and letter of credit facility (2)	—		—
Total debt	29,242		30,406

Current portion of long-term debt	(62)		(117)
Short-term debt	—		(250)
Unamortized premium, discount and debt issuance costs, net	(273)		(590)
Total long-term debt, net of premium, discount and debt issuance costs	$	28,907	$	29,449

(1)A portion of the ~~2022 SPL Senior Notes~~outstanding balance that is ~~categorized~~due within one year is classified as long-term debt because the proceeds from the expected series of sales of approximately $347 million aggregate principal amount of senior secured notes due 2037, expected to be issued in the second half of 2021, subject to customary closing conditions, will be used to strategically refinance acurrent portion of ~~2022 SPL Senior Notes and pay related fees, costs and expenses.~~long-term debt.

(2)These debt instruments are classified as short-term debt.

(3)The ~~outstanding balance~~redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of ~~June 30, 2021 was repaid in July 2021 and is categorized as short-term debt.~~

December 31, 2021. See
Convertible Notes section below for further discussion of the redemption.

Table of Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

~~Issuances, Redemptions and Repayments~~

~~The following table shows the issuances, redemptions and repayments of long-term debt during the six months ended June 30, 2021 (in millions):~~


~~Issuances~~	~~Principal Amount Issued~~
~~Three Months Ended March 31, 2021~~
~~Cheniere Partners~~ ~~— 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”) (1)~~	$	~~1,500~~

~~Three Months Ended June 30, 2021~~
~~Cheniere~~ ~~— Cheniere Term Loan Facility (2)~~	~~220~~
~~Cheniere~~ ~~— Cheniere Revolving Credit Facility~~	~~134~~
~~Six Months Ended June 30, 2021 total~~	$	~~1,854~~

~~Redemptions and Repayments~~	~~Principal Amount Redeemed/Repaid~~
~~Three Months Ended March 31, 2021~~
~~Cheniere Partners~~ ~~— 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) (1)~~	$	~~1,500~~
~~Cheniere~~ ~~— Cheniere Term Loan Facility (3)~~	~~148~~

~~Three Months Ended June 30, 2021~~
~~Cheniere~~ ~~— 2021 Cheniere Convertible Notes (2)~~	~~476~~
~~Cheniere~~ ~~— Cheniere Term Loan Facility (3)~~	~~220~~
~~Six Months Ended June 30, 2021 total~~	$	~~2,344~~

~~(1)~~Proceeds of the 2031 CQP Senior Notes, together with cash on hand, were used to redeem all of CQP’s outstanding 2025 CQP Senior Notes, resulting in the recognition of debt extinguishment costs of $54 million for the six months ended June 30, 2021 relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs.

~~(2)In May 2021, the 2021 Cheniere Convertible Notes were repaid using a combination of borrowings under the Cheniere Term Loan Facility and cash on hand upon the maturity date at par value.~~

~~(3)As of June 30, 2021, the remaining commitments under the Cheniere Term Loan Facility were terminated in accordance with the credit agreement, resulting in $4 million of loss on extinguishment of debt.~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

Credit Facilities

Below is a summary of our committed credit facilities outstanding as of ~~June 30, 2021~~March 31, 2022 (in millions):


		2020 SPL Working Capital Facility (1)		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility			2020 SPL Working Capital Facility		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Original facility size		$	1,200	$	1,500	$	8,404	$	350	$	750
Incremental commitments		0		0		1,566		850		500
Total facility size												Total facility size	$	1,200	$	750	$	1,439	$	1,200	$	1,250

Less:	Less:											Less:
Outstanding balance	Outstanding balance	0		0		2,627		0		134		Outstanding balance	—		—		1,439		—		—
Commitments prepaid or terminated		0		750		7,343		0		0

Letters of credit issued	Letters of credit issued	396		0		0		293		0		Letters of credit issued	368		—		—		276		—
Available commitment	Available commitment	$	804	$	750	$	0	$	907	$	1,116	Available commitment	$	832	$	750	$	—	$	924	$	1,250

Priority ranking	Priority ranking	Senior secured		Senior secured		Senior secured		Senior secured		Senior secured		Priority ranking	Senior secured		Senior secured		Senior secured		Senior secured		Senior secured
Interest rate on available balance	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%		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%		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%		LIBOR plus 1.75% or base rate plus 0.75% (1)		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75% (1)		LIBOR plus 1.250% - 2.375% or base rate plus 0.250% - 1.375% (1)
Weighted average interest rate of outstanding balance	Weighted average interest rate of outstanding balance	n/a		n/a		1.85%		n/a		1.82%		Weighted average interest rate of outstanding balance	n/a		n/a		2.21%		n/a		n/a
Commitment fees on undrawn balance												Commitment fees on undrawn balance	0.20%		0.49%		n/a		0.50%		0.25%
Maturity date	Maturity date	March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		December 13, 2022		Maturity date	March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		October 28, 2026

(1)~~The 2020 SPL Working Capital Facility contains customary conditions precedent~~These facilities were amended in 2021 to establish a SOFR-indexed replacement rate for extensions of credit, as well as customary affirmative and negative covenants. SPL pays a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.LIBOR.

Convertible Notes

~~Below is~~On December 6, 2021, we issued a ~~summary~~notice of ~~our convertible notes outstanding as of June 30, 2021 (in millions):~~

~~2045 Cheniere Convertible Senior Notes~~

~~Aggregate original principal~~

~~625~~

~~Debt component, net of discount and debt issuance costs~~

~~319~~

~~Equity component~~

~~194~~

~~Interest payment method~~

~~Cash~~

~~Conversion by us (1)~~

~~(2)~~

~~Conversion by holders (1)~~

~~(3)~~

~~Conversion basis~~

~~Cash and/or stock~~

~~Conversion value in excess of principal~~

~~Maturity date~~

~~March 15, 2045~~

~~Contractual interest rate~~

~~4.25~~

~~Effective interest rate (4)~~

~~9.4~~

~~Remaining debt discount and debt issuance costs amortization period (5)~~

~~23.7 years~~

~~(1)Conversion is subject to various limitations and conditions, which have not been met as of the balance sheet date.~~

~~(2)Redeemable at any time at a~~ redemption ~~price payable in cash equal to the accreted amount of the~~for all $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior ~~Notes~~Notes. The notice of redemption allowed holders to ~~be redeemed, plus accrued and unpaid interest, if any,~~elect to ~~such redemption date.~~

~~(3)Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may~~ convert their notes ~~regardless~~at any time prior to a specified deadline on December 31, 2021, with settlement of ~~these circumstances.~~such converted notes in cash, as elected by us, on January 5, 2022. The impact of holders electing conversion ~~rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of~~was immaterial to the Consolidated Financial Statements. The 2045 Cheniere Convertible Senior Notes

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

~~which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon~~ not converted were redeemed on January 5, 2022 with borrowings under the ~~occurrence of certain specified events).~~

~~(4)Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.~~

~~(5)We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity.~~Cheniere Revolving Credit Facility.

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, our subsidiaries’ and its restricted subsidiaries’ ability to make certain investments or pay dividends or distributions. SPL, CQP and CCH are restricted from making distributions under agreements governing their respective 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 ~~June 30, 2021,~~March 31, 2022, each of our issuers was in compliance with all covenants related to their respective debt agreements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Interest Expense

Total interest expense, net of capitalized interest, including interest expense related to our convertible notes, consisted of the following (in millions):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
Interest cost on convertible notes:	Interest cost on convertible notes:									Interest cost on convertible notes:
Interest per contractual rate	Interest per contractual rate	$	11	$	57	$	23	$	120	Interest per contractual rate		$	—	$	12
Amortization of debt discount	Amortization of debt discount	3		20		8		34		Amortization of debt discount		—		5
Amortization of debt issuance costs	Amortization of debt issuance costs	0		4		0		7		Amortization of debt issuance costs		—		—
Total interest cost related to convertible notes	Total interest cost related to convertible notes	14		81		31		161		Total interest cost related to convertible notes		—		17
Interest cost on debt and finance leases excluding convertible notes	Interest cost on debt and finance leases excluding convertible notes	387		388		787		779		Interest cost on debt and finance leases excluding convertible notes		372		400
Total interest cost	Total interest cost	401		469		818		940		Total interest cost		372		417
Capitalized interest	Capitalized interest	(33)		(62)		(94)		(121)		Capitalized interest		(23)		(61)
Total interest expense, net of capitalized interest	Total interest expense, net of capitalized interest	$	368	$	407	$	724	$	819	Total interest expense, net of capitalized interest		$	349	$	356

Fair Value Disclosures

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


		June 30, 2021				December 31, 2020					March 31, 2022				December 31, 2021
		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value			Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior notes — Level 2 (1)	Senior notes — Level 2 (1)	$	24,700	$	27,503	$	24,700	$	27,897	Senior notes — Level 2 (1)	$	24,550	$	25,196	$	24,550	$	26,725
Senior notes — Level 3 (2)	Senior notes — Level 3 (2)	2,771		3,350		2,771		3,423		Senior notes — Level 3 (2)	3,253		3,356		3,253		3,693
Credit facilities — Level 3 (3)		2,791		2,791		2,915		2,915
2021 Cheniere Convertible Notes — Level 3 (2)		0		0		476		480

2045 Cheniere Convertible Senior Notes — Level 1 ~~(4)~~(3)	2045 Cheniere Convertible Senior Notes — Level 1 ~~(4)~~(3)	625		527		625		496		2045 Cheniere Convertible Senior Notes — Level 1 ~~(4)~~(3)	—		—		625		526

(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 our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.

(3)The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

~~(4)The Level~~ 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

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.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE ~~11—~~10—LEASES

Our leased assets consist primarily of LNG vessel time charters (“vessel charters”) and additionally include tug vessels, office space and facilities and land sites. All of our leases are classified as operating leases except for our tug vessels supporting the Corpus Christi LNG Terminal, which are classified as finance leases.

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):


			June 30,		December 31,				March 31,		December 31,
		Consolidated Balance Sheets Location	2021		2020			Consolidated Balance Sheets Location	2022		2021
Right-of-use assets—Operating	Right-of-use assets—Operating	Operating lease assets	$	1,698	$	759	Right-of-use assets—Operating	Operating lease assets	$	1,975	$	2,102
Right-of-use assets—Financing	Right-of-use assets—Financing	Property, plant and equipment, net of accumulated depreciation	52		53		Right-of-use assets—Financing	Property, plant and equipment, net of accumulated depreciation	49		50
Total right-of-use assets	Total right-of-use assets		$	1,750	$	812	Total right-of-use assets		$	2,024	$	2,152

Current operating lease liabilities	Current operating lease liabilities	Current operating lease liabilities	$	365	$	161	Current operating lease liabilities	Current operating lease liabilities	$	527	$	535
Current finance lease liabilities	Current finance lease liabilities	Other current liabilities	2		2		Current finance lease liabilities	Other current liabilities	2		2
Non-current operating lease liabilities	Non-current operating lease liabilities	Operating lease liabilities	1,332		597		Non-current operating lease liabilities	Operating lease liabilities	1,423		1,541
Non-current finance lease liabilities	Non-current finance lease liabilities	Finance lease liabilities	57		57		Non-current finance lease liabilities	Finance lease liabilities	57		57
Total lease liabilities	Total lease liabilities		$	1,756	$	817	Total lease liabilities		$	2,009	$	2,135

The following table shows the classification and location of our lease costs on our Consolidated Statements of Operations (in millions):


		Consolidated Statements of Operations Location		Three Months Ended June 30,								Six Months Ended June 30,								Consolidated Statements of Operations Location					Three Months Ended March 31,
			2021			2020				2021				2020							Consolidated Statements of Operations Location					2022			2021
Operating lease cost (a)	Operating lease cost (a)		Operating costs and expenses (1)			$	145			$	98			$	296			$	239					Operating lease cost (a)			$	202		$	151
Finance lease cost:	Finance lease cost:																						Finance lease cost:
Amortization of right-of-use assets	Amortization of right-of-use assets	Depreciation and amortization expense		1				1				2				2						Amortization of right-of-use assets	Depreciation and amortization expense				1			1
Interest on lease liabilities	Interest on lease liabilities	Interest expense, net of capitalized interest		3				3				5				5						Interest on lease liabilities	Interest expense, net of capitalized interest				2			2

Total lease cost	Total lease cost			$	149			$	102			$	303			$	246					Total lease cost					$	205		$	154

(a) Included in operating lease cost:	(a) Included in operating lease cost:																					(a) Included in operating lease cost:
Short-term lease costs	Short-term lease costs			$	30			$	16			$	81			$	51					Short-term lease costs					$	41		$	51
Variable lease costs	Variable lease costs			11				4				13				9						Variable lease costs					9			2

(1)Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

Future annual minimum lease payments for operating and finance leases as of March 31, 2022 are as follows (in millions):


Years Ending December 31,	Operating Leases (1)		Finance Leases
2022	$	450	$	10
2023	514		10
2024	457		10
2025	244		10
2026	218		10
Thereafter	294		117
Total lease payments	2,177		167
Less: Interest	(227)		(108)
Present value of lease liabilities	$	1,950	$	59

(1)Does not include approximately $3.2 billion of legally binding minimum payments primarily for vessel charters which were executed as of March 31, 2022 but will commence in future periods and have fixed minimum lease terms of up to 10 years.

2120

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

~~Future annual minimum lease payments for operating and finance leases as of June 30, 2021 are as follows (in millions):~~

Years Ending December 31, Operating Leases (1) Finance Leases
2021 $ 227 $ 5
2022 397 10
2023 358 10
2024 313 10
2025 213 10
Thereafter 448 127
Total lease payments 1,956 172
Less: Interest (259) (113)
Present value of lease liabilities $ 1,697 $ 59

(1) Does not include $984 million of legally binding minimum lease payments primarily for vessel charters which were executed as of June 30, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to seven years.

The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases:


		June 30, 2021		December 31, 2020			March 31, 2022		December 31, 2021
		Operating Leases	Finance Leases	Operating Leases	Finance Leases		Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	Weighted-average remaining lease term (in years)	6.4	17.2	8.2	17.7	Weighted-average remaining lease term (in years)	5.4	16.4	5.6	16.7
Weighted-average discount rate (1)	Weighted-average discount rate (1)	4.1%	16.2%	5.4%	16.2%	Weighted-average discount rate (1)	3.5%	16.2%	3.6%	16.2%

(1)The finance leases commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

The following table includes other quantitative information for our operating and finance leases (in millions):


		Six Months Ended June 30,				Three Months Ended March 31,
		2021		2020				2022		2021
Cash paid for amounts included in the measurement of lease liabilities:	Cash paid for amounts included in the measurement of lease liabilities:						Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows used in operating leases		$	201	$	157
Operating cash flows used in finance leases		5		5
Operating cash flows from operating leases							Operating cash flows from operating leases	$	151	$	97
Operating cash flows from finance leases							Operating cash flows from finance leases	2		2

Right-of-use assets obtained in exchange for operating lease liabilities	Right-of-use assets obtained in exchange for operating lease liabilities	1,112		246			Right-of-use assets obtained in exchange for operating lease liabilities	7		507

LNG Vessel Subcharters

From time to time, we sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. As of ~~June 30, 2021~~March 31, 2022 and December 31, ~~2020,~~2021, we had $4 million and ~~0, respectively, in~~$15 million future minimum sublease payments to be received from LNG vessel subcharters. The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
Fixed income	Fixed income	$	8	$	15	$	11	$	52	Fixed income		$	32	$	3
Variable income	Variable income	5		8		6		23		Variable income		19		1
Total sublease income	Total sublease income	$	13	$	23	$	17	$	75	Total sublease income		$	51	$	4

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE ~~12—~~11—REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers ~~during the three and six months ended June 30, 2021 and 2020~~ (in millions):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
LNG revenues ~~(1)~~	LNG revenues ~~(1)~~	$	3,297	$	2,340	$	6,336	$	4,744	LNG revenues ~~(1)~~		$	7,564	$	3,039
Regasification revenues	Regasification revenues	67		68		134		135		Regasification revenues		68		67
Other revenues	Other revenues	24		16		44		38		Other revenues		25		20

Total revenues from customers	Total revenues from customers	3,388		2,424		6,514		4,917		Total revenues from customers		7,657		3,126
Net derivative gain (loss) (2)		(384)		(45)		(424)		119
Net derivative loss (1)										Net derivative loss (1)		(224)		(40)
Other ~~(3)~~(2)	Other ~~(3)~~(2)	13		23		17		75		Other ~~(3)~~(2)		51		4
Total revenues	Total revenues	$	3,017	$	2,402	$	6,107	$	5,111	Total revenues		$	7,484	$	3,090

(1) LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and six months ended June 30, 2020, we recognized $708 million and $761 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $458 million would have been recognized subsequent to June 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended June 30, 2020 and six months ended June 30, 2021 excluded $53 million and $38 million, respectively, that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with the customers. We did 0t have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and six months ended June 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

~~(2)~~ See Note 6—6 —Derivative Instruments for additional information about our derivatives.

~~(3)~~ (2)Includes revenues from LNG vessel subcharters. See Note ~~11—~~1 0 —Leases for additional information about our subleases.

Contract Assets and Liabilities

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

June 30, December 31,
2021 2020
Contract assets, net of current expected credit losses $ 109 $ 80



	March 31,		December 31,
	2022		2021
Contract assets, net of current expected credit losses	$	149	$	140

~~Contract assets represent our right to consideration for transferring goods or services to the customer under the terms~~

Table of a sales contract when the associated consideration is not yet due. Changes in contract assets during the six months ended June 30, 2021 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due.Contents

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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~~Three Months Ended ~~June 30, 2021~~March 31, 2022

Deferred revenue, beginning of period

~~138~~194

Cash received but not yet recognized in revenue

~~105~~169

Revenue recognized from prior period deferral

~~(138)~~(194)

Deferred revenue, end of period

~~105~~169

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been ~~satisfied as of June 30, 2021 and December 31, 2020:~~satisfied:


		June 30, 2021			December 31, 2020				March 31, 2022			December 31, 2021
		Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)		Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues	LNG revenues	$	101.1	10	$	102.3	10	LNG revenues	$	107.1	9	$	107.1	9
Regasification revenues	Regasification revenues	2.0		4	2.1		5	Regasification revenues	1.8		4	1.9		4
Total revenues	Total revenues	$	103.1		$	104.4		Total revenues	$	108.9		$	109.0

(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 ~~53%~~66% and ~~26%~~51% of our LNG revenues from contracts included in the table above during the three months ended ~~June 30,~~March 31, 2022 and 2021, ~~and 2020, respectively, and approximately 52% and 34% of our LNG revenues from contracts included in the table above during the six months ended June 30, 2021 and 2020,~~ respectively, were related to variable consideration received from customers. During ~~each of~~ the three ~~and six~~ months ended ~~June 30,~~March 31, 2022 and 2021, approximately ~~5% of our regasification revenues were related to variable consideration received from customers~~6% and ~~during each of the three and six months ended June 30, 2020, approximately 6%~~3%, respectively, 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 FID 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.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE ~~13—~~12—RELATED PARTY TRANSACTIONS

Natural Gas Supply Agreements

~~SPL and~~ CCL ~~are~~Natural Gas Supply Agreement

CCL was party to a natural gas supply ~~agreements~~agreement with a related ~~parties~~party in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the ~~Liquefaction Projects. These~~CCL Project. The related ~~parties are partially owned~~party entity was acquired by ~~The Blackstone Group Inc., who also partially owns Cheniere Partners’ limited partner interests.~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

~~SPL Natural Gas Supply Agreement~~

~~The term of the SPL agreement is for five years, which can commence no earlier than~~a non-related party on November 1, ~~2021 and no later than November 1, 2022, following the achievement~~2021; therefore, as of ~~contractually-defined conditions precedent. As of both June 30, 2021 and December 31, 2020, the notional amount for~~such date, this agreement ~~was 91 TBtu and had~~ceased to be considered a ~~fair value~~related party agreement. During the three months ended March 31, 2021, we recorded $35 million of 0.

~~CCL Natural Gas Supply Agreement~~

~~The term~~cost of ~~the CCL agreement extends through March 2022. Under this agreement, CCL recorded $13 million in accrued liabilities, as of both June 30, 2021 and December 31, 2020.~~

~~The Liquefaction Supply Derivatives~~sales related to this agreement, ~~are recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount):~~

June 30, December 31,
2021 2020
Current derivative assets $ 4 $ 3
Derivative assets 7 1
Notional amount (in TBtu) 132 60

~~We recorded the following amounts on our Consolidated Statements~~ of ~~Operations during the three and six months ended June 30, 2021 and 2020~~which $1 millionwas related to ~~this agreement (in millions):~~

Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
Cost of sales (a) $ 36 $ 25 $ 71 $ 48
(a) Included in costs of sales:
Liquefaction Supply Derivative gain $ 6 $ 1 $ 7 $ 2
Liquefaction Supply Derivatives gain.

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 SPL Project, with initial primary terms of up to 10 years with extension rights. This related party is partially owned by Brookfield Asset Management, Inc., who indirectly acquired a portion of ~~Cheniere Partners’~~CQP’s limited partner interests in September 2020. We recorded operating and maintenance expense of $12 million and ~~$22 million and cost of sales of $1 million and $1~~$10 million during the three ~~and six~~ months ended ~~June 30,~~March 31, 2022 and 2021, ~~respectively, and~~respectively. Additionally, we recorded accrued liabilities of $5 million and $4 million as of ~~both June 30, 2021~~March 31, 2022 and December 31, ~~2020~~2021, respectively, with this related party.

CCL is party to natural gas transportation agreements with Midship Pipeline Company, LLC (“Midship Pipeline”) in the ordinary course of business for the operation of the CCL Project, for a period of 10 years which began in May 2020. We account for our investment in Midship Holdings, LLC, which manages the business and affairs of Midship Pipeline, as an equity method investment. We recorded operating and maintenance expense of $2 million during both the three months ended March 31, 2022 and 2021. Additionally, we recorded accrued liabilities of $1 million as of both March 31, 2022 and December 31, 2021 with this related party.

Operation and Maintenance Service Agreements

Cheniere LNG O&M Services, LLC (“O&M Services”), our wholly owned subsidiary, provides the development, construction, operation and maintenance services to Midship Pipeline pursuant to agreements in which O&M Services receives an agreed upon fee and reimbursement of costs incurred. O&M Services recorded $1$2 million ~~and $3 million~~ in each of the three months ended ~~June 30,~~March 31, 2022 and 2021, ~~and 2020, respectively, and $3 million and $6 million in the six months ended June 30, 2021 and 2020, respectively,~~ of other revenues and $1 million and $2 million of ~~accounts receivable~~other receivables as of ~~June 30, 2021~~March 31, 2022 and December 31, ~~2020,~~2021, respectively, for services provided to Midship Pipeline under these agreements.

NOTE ~~14—~~13—INCOME TAXES

We recorded an income tax benefit of ~~$93~~$191 million and $4income tax provision of $89 million during the three ~~and six~~ months ended ~~June 30,~~March 31, 2022 and 2021, ~~respectively, and~~respectively.

Our effective tax rate of 19.7% for the three months ended March 31, 2022 corresponds to an income tax ~~provision of $63 million and $194 million during the three and six months ended June 30, 2020, respectively. The effective tax rates~~benefit recorded for the ~~three~~period and ~~six months ended June 30, 2021 were 41.5% and (0.9)%, respectively, and do not bear a customary relationship to statutory income tax rates due to a combination of factors including income~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

allocated to non-controlling interest that is not taxable to Cheniere and a $58 million discrete tax benefit related to releasing a portion of our valuation allowance caused by a change in tax law allowing for indefinite Louisiana net operating loss (“NOL”) carryover. The effective tax rates for the three and six months ended June 30, 2020 were 13.5% and 16.2%, respectively, which werewas lower than the ~~21% federal~~ statutory income tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere partially offset by ~~a $38 million discrete~~ tax ~~expense~~benefits related to stock-based compensation awards that vested in the quarter. Our effective tax rate of 13.5% for the three months ended March 31, 2021 corresponds to an ~~internal restructuring.~~income tax provision recorded for the period and was lower than the statutory income tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere.

~~NOTE 15—SHARE-BASED COMPENSATION~~

~~We have granted restricted stock shares, restricted stock units, performance stock units~~Our effective tax rate is subject to variation prospectively due to variability in our pre-tax and ~~phantom units to employees and non-employee directors under the 2011 Incentive Plan, as amended (the “2011 Plan”)~~taxable earnings and the 2020 Incentive Plan. For the six months ended June 30, 2021, we granted 1.5 million restricted stock units and 0.3 million performance stock units at target performance under the 2020 Plan to certain employees. Additionally, 0.2 million incremental sharesproportion of ~~our common stock were issued based on performance results from previously-granted performance stock unit awards.~~

Restricted stock units are stock awards that vest over a service period of three years and entitle the holder to receive shares of our common stock upon vesting, subject to restrictions on transfer and to a risk of forfeiture if the recipient terminates employment with us prior to the lapse of the restrictions. Performance stock units provide for cliff vesting after a period of three years with payouts based on metrics dependent upon market and performance achieved over the defined performance period compared to pre-established performance targets. The settlement amounts of the awards are based on market and performance metrics which include cumulative distributable cash flow per share, and in certain circumstances, absolute total shareholder return (“ATSR”) of our common stock. Where applicable, the compensation for performance stock units is based on fair value assigned to the market metric of ATSR using a Monte Carlo model upon grant, which remains constant through the vesting period, and a performance metric, which will vary due to changing estimates regarding the expected achievement of the performance metric of cumulative distributable cash flow per share. The number of shares that may be earned at the end of the vesting period ranges from 0% up to 300% of the target award amount. Both restricted stock units and performance stock units will be settled in Cheniere common stock (on a one-for-one basis) and are classified as equity awards, however, a portion of the performance stock units granted in 2021 will partially settle in cash, subject to individual limits. The portion of performance stock units expected to settle in Cheniere common stock (on a one-for-one basis) are classified as equity awards and the portion of performance stock units expected to settle in cash are classified as liability awards.

~~Total share-based compensation consisted of the following (in millions):~~

Three Months Ended June 30, Six Months Ended June 30,
2021 2020 2021 2020
Share-based compensation costs, pre-tax:
Equity awards $ 31 $ 31 $ 64 $ 60
Liability awards 1 1 2 1
Total share-based compensation 32 32 66 61
Capitalized share-based compensation (1) (3) (3) (4)
Total share-based compensation expense $ 31 $ 29 $ 63 $ 57
Tax benefit associated with share-based compensation expense $ 1 $ 1 $ 27 $ 19

~~NOTE 16—NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS~~

~~Basic net income (loss) per share~~such earnings attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS reflects potential dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued. The dilutive effect of unvested stock is calculated using the treasury-stock method and the dilutive effect of convertible securities is calculated using the if-converted method.

non-controlling interests.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 14—NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

The following table reconciles basic and diluted weighted average common shares outstanding ~~for the three and six months ended June 30, 2021 and 2020~~ (in millions, except per share data):


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
Net income (loss) attributable to common stockholders	Net income (loss) attributable to common stockholders	$	(329)	$	197	$	64	$	572	Net income (loss) attributable to common stockholders		$	(865)	$	393

Weighted average common shares outstanding:	Weighted average common shares outstanding:									Weighted average common shares outstanding:
Basic	Basic	253.5		252.1		253.2		252.6		Basic		254.0		252.9
Dilutive unvested stock	Dilutive unvested stock	0		0.3		1.5		0.7		Dilutive unvested stock		—		1.5

Dilutive convertible securities										Dilutive convertible securities		—		4.5
Diluted	Diluted	253.5		252.4		254.7		253.3		Diluted		254.0		258.9

Net income (loss) per share attributable to common stockholders—basic (1)	Net income (loss) per share attributable to common stockholders—basic (1)	$	(1.30)	$	0.78	$	0.25	$	2.27	Net income (loss) per share attributable to common stockholders—basic (1)		$	(3.41)	$	1.56
Net income (loss) per share attributable to common stockholders—diluted (1)	Net income (loss) per share attributable to common stockholders—diluted (1)	$	(1.30)	$	0.78	$	0.25	$	2.26	Net income (loss) per share attributable to common stockholders—diluted (1)		$	(3.41)	$	1.54

(1)Earnings per share in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

Potentially dilutive securities that were not included in the diluted net income (loss) per share computations because their effects would have been anti-dilutive were as follows (in millions):


		Three Months Ended June 30,		Six Months Ended June 30,			Three Months Ended March 31,
		2021	2020	2021	2020			2022	2021
Unvested stock (1)	Unvested stock (1)	1.5	2.8	0	2.5	Unvested stock (1)		2.0	1.9

2045 Cheniere Convertible Senior Notes(2)	2045 Cheniere Convertible Senior Notes(2)	4.5	4.5	4.5	4.5	2045 Cheniere Convertible Senior Notes(2)		0.3	—
Total potentially dilutive common shares	Total potentially dilutive common shares	6.0	7.3	4.5	7.0	Total potentially dilutive common shares		2.3	1.9

(1)Includes the impact of unvested shares containing performance conditions to the extent that the underlying performance conditions are satisfied based on actual results as of the respective dates.

(2)As described in Note 9—Debt, the 2045 Cheniere Convertible Senior Notes were redeemed or converted in cash on January 5, 2022. However, the adoption of ASU 2020-06 on January 1, 2022 required a presumption of share settlement for the purpose of calculating the impact to diluted earnings per share during the period the notes were outstanding in 2022. Such impact was anti-dilutive as a result of the reported net loss attributable to common shareholders during the period. See Note 1—Nature of Operations and Basis of Presentation for further discussion of our adoption of ASU 2020-06.

NOTE ~~17—~~15—STOCKHOLDERS’ DEFICIT

Share Repurchase Programs

On September 7, 2021, the Board of Directors authorized a reset in the previously existing share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. The following table presents information with respect to repurchases of common stock (in millions, except per share data):


	Three Months Ended March 31,
		2022		2021
Aggregate common stock repurchased		0.24		—
Weighted average price paid per share		$	104.21	$	—
Total amount paid		$	25	$	—

As of March 31, 2022, we had up to $973 million of the share repurchase program available.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Dividends

On January 25, 2022, we declared a quarterly dividend of $0.33 per share of common stock that was paid on February 28, 2022 to shareholders of record as of February 7, 2022. On April 26, 2022, we declared a quarterly dividend of $0.33 per share of common stock that is payable on May 17, 2022 to shareholders of record as of May 10, 2022.

NOTE 16—CUSTOMER CONCENTRATION

The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with ~~accounts receivable,~~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 ~~accounts receivable,~~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:~~customers, respectively:


		Percentage of Total Revenues from External Customers				Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers					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,			Three Months Ended March 31,		March 31,	December 31,

		2021	2020	2021	2020		2021	2020				2022	2021	2022	2021
Customer A	Customer A	14%	15%	15%	15%		*	14%	Customer A			*	15%	*	10%
Customer B	Customer B	12%	12%	12%	10%		*	12%	Customer B			*	12%	*	*
Customer C	Customer C	*	10%	11%	*		*	*	Customer C			*	13%	*	*
Customer D									Customer D			*	*	10%	*

* Less than 10%

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE ~~18—~~17—SUPPLEMENTAL CASH FLOW INFORMATION

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

Six Months Ended June 30,
2021 2020
Cash paid during the period for interest on debt, net of amounts capitalized $ 675 $ 750
Cash paid for income taxes, net of refunds 1 1

The balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities was $264 million and $222 million as of June 30, 2021 and 2020, respectively.


	Three Months Ended March 31,
	2022		2021
Cash paid during the period for interest on debt, net of amounts capitalized	$	195	$	211
Cash paid for income taxes, net of refunds	4		—
Non-cash investing and financing activities:
Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	400		360

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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” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). 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 that we expect to commence or complete construction of our proposed LNG terminals, liquefaction facilities, pipeline facilities 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 the amount~~relating to Cheniere’s capital deployment, including intent, ability, extent, and timing of capital expenditures, debt repayment, dividends, and share repurchases;

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

•statements relating to the construction of our Trains and pipelines, 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 or pipelines, including the financing of such Trains or pipelines;

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

•statements regarding our anticipated LNG and natural gas marketing activities;

•statements regarding the ~~outbreak of~~ COVID-19 pandemic and its impact on our business and operating results, including any customers not taking delivery of LNG cargoes, the ongoing ~~credit worthiness~~creditworthiness of our contractual counterparties, any disruptions in our operations or construction of our Trains and the health and safety of our employees, and on our customers, the global economy and the demand for LNG; 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

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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 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, ~~2020~~20 21. 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 ~~of Business~~

•Overview of Significant Events

•Results of Operations

•Liquidity and Capital Resources

•~~Off-Balance Sheet Arrangements~~

•Summary of Critical Accounting Estimates

•Recent Accounting Standards

Overview ~~of Business~~

Cheniere, a Delaware corporation, is a Houston-based energy infrastructure company primarily engaged in LNG-related businesses. 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, turned 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 and other industrial uses. 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 and operate the natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG ~~terminal in Louisiana,~~Terminal”), one of the largest LNG production facilities in the world, through our ownership interest in and management agreements with ~~Cheniere Partners,~~CQP, which is a publicly traded limited partnership that we ~~created~~formed in 2007. As of ~~June 30, 2021,~~March 31, 2022, we owned 100% of the general partner interest and a 48.6% ~~of the~~ limited partner ~~interest~~interests in ~~Cheniere Partners. We also own and operate the Corpus Christi LNG terminal in Texas, which is wholly owned by us.~~

~~Cheniere Partners owns the~~CQP. The Sabine Pass LNG ~~terminal located in Cameron Parish, Louisiana, which~~Terminal has ~~natural gas liquefaction facilities consisting of five~~six operational ~~natural gas liquefaction~~ Trains, ~~and one additional~~with Train ~~under construction that is expected to be substantially completed in the first half of~~6 achieving substantial completion on February 4, 2022, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG ~~terminal~~Terminal also has operational regasification facilities that include five LNG storage tanks with aggregate capacity of approximately 17 Bcfe, two existing marine berths and one under construction that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4 Bcf/d. ~~Cheniere Partners~~CQP also owns a 94-mile pipeline through its

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subsidiary, CTPL, that interconnects the Sabine Pass LNG ~~terminal~~Terminal with a number of large interstate ~~pipelines.~~pipelines (the “Creole Trail Pipeline”).

We also own and operate the ~~Corpus Christi LNG terminal~~natural gas liquefaction and export facility located near Corpus Christi, Texas ~~and currently operate~~(the “Corpus Christi LNG Terminal”) through CCL, which has natural gas liquefaction facilities consisting of three operational Trains for a total production capacity of approximately 15 mtpa of LNG. Additionally, we own and operate through CCP a ~~23-mile~~21.5-mile natural gas supply pipeline that interconnects the Corpus Christi LNG ~~terminal~~Terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Trains, the “CCL Project”) ~~through our subsidiaries CCL and CCP, respectively, as part of the CCH Group.~~. The CCL Project also ~~contains~~includes three LNG storage tanks with aggregate capacity of approximately 10 Bcfe and two marine berths that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters.

We ~~have contracted approximately 85%~~are the largest producer of LNG in the United States and the second largest LNG producer globally, based on the total production capacity ~~from the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) on a term basis, with~~of our asset platforms of approximately ~~17 years of weighted average remaining life~~45 mtpa as of June 30, 2021. This includes volumes contracted under SPAs in which the customers are required to pay a fixed fee with respect to the contracted volumes irrespective of their election to cancel or suspend deliveries of LNG cargoes, as well as a portion of volumes contracted under integrated production marketing (“IPM”) gas supply agreements.March 31, 2022.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG ~~terminal~~Terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) through our subsidiary CCL Stage III for up to seven midscale Trains with an expected total production capacity of ~~approximately~~over 10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and operate the expansion project.

Our customer arrangements provide us with significant, stable and long-term cash flows. We contract 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 the gas producer sells to us gas on a global LNG index price, less a fixed liquefaction fee, shipping and other costs. We have contracted over 95% of the total production capacity from the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”), including those contracts executed to support Corpus Christi Stage ~~III has entered into various~~3, through the 2020s and over 90% contracted through the mid-2030s. Excluding contracts with terms less than 10 years, our SPAs and IPM ~~gas supply agreements.~~agreements had approximately 17 years of weighted average remaining life as of March 31, 2022. We also market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. In March 2022, the DOE authorized the export of an additional 152.64 Bcf/yr and 108.16 Bcf/yr of domestically produced LNG by vessel from the Sabine Pass LNG Terminal and the Corpus Christi LNG Terminal, respectively, through December 31, 2050 to non-FTA countries, that were previously authorized for FTA countries only. For further discussion of the contracted future cash flows under our revenue arrangements, see the liquidity and capital resources disclosures in our annual report on Form 10-K for the fiscal year ended December 31, 2021.

We remain focused on 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 Projects as a result of debottlenecking and other optimization projects. We hold significant land positions at both the Sabine Pass LNG ~~terminal~~Terminal and the Corpus Christi LNG ~~terminal~~Terminal, which provide opportunity for further liquefaction capacity expansion. The development of these sites 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 can make a final investment decision (“FID”).

Additionally, we are committed to the responsible and proactive management of our most important environmental, social and governance (“ESG”) impacts, risks and opportunities. We published our 2020 Corporate Responsibility (“CR”) report, which details our strategy and progress on ESG issues, as well as our efforts on integrating climate considerations into our business strategy and taking a leadership position on increased environmental transparency, including conducting a climate scenario analysis and our plan to provide LNG customers with Cargo Emission Tags. In April 2022, we announced a collaboration with natural gas midstream companies, methane detection technology providers and leading academic institutions to implement quantification, monitoring, reporting and verification of greenhouse gas emissions at natural gas gathering, processing, transmission and storage systems specific to our supply chain. Our CR report is available at cheniere.com/IMPACT. Information on our website, including the CR report, is not incorporated by reference into this Quarterly Report on Form 10-Q.

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Overview of Significant Events

Our significant events since January 1, ~~2021~~2022 and through the filing date of this Form 10-Q include the following:

Strategic

•In ~~July 2021,~~May 2022, CCL Stage III entered into an IPM ~~gas supply~~ agreement with ~~Tourmaline Oil Marketing Corp.~~ARC Resources U.S. Corp, a subsidiary of ARC Resources, Ltd., to purchase 140,000 MMBtu per day of natural gas at a price based on ~~the Platts Japan Korea Marker (“JKM”),~~JKM, for a term of approximately 15 years ~~beginning in early 2023.~~commencing with commercial operations of Train 7 of Corpus Christi Stage 3, subject to FID of Corpus Christi Stage 3.

•~~On July 1, 2021, the board~~In March 2022, CCL Stage III entered into an EPC contract with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for Corpus Christi Stage 3 for a contract price of ~~directors of the Company (the “Board”) appointed Mses. Patricia K. Collawn~~approximately $5.5 billion, subject to adjustment only by change order. CCL Stage III also issued a limited notice to proceed to Bechtel to commence early engineering, procurement and Lorraine Mitchelmore to serve as members of the Board. Ms. Collawn was appointed to the Audit Committee and the Compensation Committee of the Board, and Ms. Mitchelmore was appointed to the Audit Committee and the Governance and Nominating Committee of the Board.site works.

•~~Our subsidiaries~~In March 2022, CCL amended its existing long-term SPA with Engie SA (“Engie”), increasing the volume Engie has agreed to purchase from CCL to approximately 0.9 mtpa of LNG on a free-on-board basis, and extending the term to approximately 20 years, which began in September 2021.

•In February 2022, CCL Stage III amended the IPM agreement previously entered into ~~SPAs~~ with ~~multiple counterparties~~EOG Resources, Inc. (“EOG”), increasing the volume and term of natural gas supply from 140,000 MMBtu per day for ~~portfolio volumes aggregating approximately 12 million tonnes of LNG~~10 years, to 420,000 MMBtu per day for 15 years, with pricing continuing to be ~~delivered between 2021~~based on the Platts Japan Korea Marker (“JKM”). Under the amended IPM agreement, supply is targeted to commence upon completion of Trains 1, 4 and ~~2032.~~5 of Corpus Christi Stage 3. In addition, the previously executed gas supply agreement, under which EOG sells 300,000 MMBtu per day to CCL Stage III at a price indexed to Henry Hub, has been extended by 5 years, resulting in a 15 year term that is expected to commence upon start-up of the amended IPM agreement.

Operational

•As of ~~July 31, 2021, approximately 1,675~~April 30, 2022, over 2,100 cumulative LNG cargoes totaling ~~approximately 115~~over 145 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Projects.

•On ~~March 26, 2021,~~February 4, 2022, substantial completion of Train 36 of the ~~CCL~~SPL Project was achieved.

Financial

•~~We completed the following financing transactions:~~

◦During 2021, SPL entered into a series of note purchase agreements for the sale of approximately $347 million aggregate principal amount of Senior Secured Notes due 2037 (the “2037 SPL Private Placement Senior Secured Notes”) on a private placement basis. The 2037 SPL Private Placement Senior Secured Notes are expected to be issued in the second half of 2021, subject to customary closing conditions, and the net proceeds will be used to strategically refinance a portion of SPL’s outstanding 6.25% SPL Senior Secured

~~Notes due 2022 and pay related fees, costs and expenses. The 2037 SPL Private Placement Senior Secured Notes will be fully amortizing, with a weighted average life of over 10 years.~~

◦In March 2021, Cheniere Partners issued an aggregate principal amount of approximately $1.5 billion of 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”). The net proceeds of the 2031 CQP Senior Notes, along with cash on hand, were used to refinance the 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) and to pay fees and expenses in connection with the refinancing.

•During the ~~six~~three months ended ~~June 30, 2021,~~March 31, 2022, we used $1.1 billion of available cash to reduce our outstanding indebtedness, of which over $0.8 billion was the redemption or prepayment of long-term indebtedness pursuant to our capital allocation plan, including the early redemption of our 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) in January 2022.

•Also in line with our ~~previously announced~~ capital allocation ~~priorities,~~plan, during the three months ended March 31, 2022, we ~~fully repaid the $624~~repurchased 238,537 shares of our common stock as part of our share repurchase program for $25 million and paid a quarterly dividend of total outstanding indebtedness under Cheniere’s term loan facility (“Cheniere Term Loan Facility”) and Cheniere’s 4.875% convertible notes due May 2021 (“2021 Cheniere Convertible Notes”) with $500 million$0.33 per share of ~~available cash and the remainder from borrowings under the Cheniere Revolving Credit Facility.~~

•~~In January 2021, the term commenced~~common stock on ~~Cheniere Marketing International LLP’s 25 year SPA with CPC Corporation, Taiwan.~~

•In February 2021, Fitch Ratings (“Fitch”) changed the outlook of SPL’s senior secured notes rating to positive from stable and the outlook of Cheniere Partners’ long-term issuer default rating and senior unsecured notes rating to positive from stable.

•~~In April 2021, S&P Global Ratings changed the outlook of Cheniere and Cheniere Partners’ ratings to positive from negative.~~28, 2022.

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Results of Operations

The following charts summarize the total revenues and total LNG volumes loaded from our Liquefaction Projects ~~(including both operational and commissioning volumes)~~ during the ~~six~~three months ended ~~June 30, 2021~~March 31, 2022 and ~~2020:~~2021:

The following table summarizes the volumes of operational and commissioning LNG cargoes that were loaded from the Liquefaction Projects, which were recognized on our Consolidated Financial ~~Statements during the three and six months ended June 30, 2021:~~Statements:

Three Months Ended June 30, 2021 Six Months Ended June 30, 2021
(in TBtu) Operational Commissioning Operational Commissioning
Volumes loaded during the current period 499 — 947 28
Volumes loaded during the prior period but recognized during the current period 32 6 26 3
Less: volumes loaded during the current period and in transit at the end of the period (23) — (23) —
Total volumes recognized in the current period 508 6 950 31

~~Net income attributable to common stockholders~~

Three Months Ended June 30, Six Months Ended June 30,
(in millions, except per share data) 2021 2020 Change 2021 2020 Change
Net income (loss) attributable to common stockholders $ (329) $ 197 $ (526) $ 64 $ 572 $ (508)
Net income (loss) per share attributable to common stockholders—basic (1.30) 0.78 (2.08) 0.25 2.27 (2.02)
Net income (loss) per share attributable to common stockholders—diluted (1.30) 0.78 (2.08) 0.25 2.26 (2.01)


	Three Months Ended March 31, 2022
(in TBtu)		Operational	Commissioning
Volumes loaded during the current period		572	13
Volumes loaded during the prior period but recognized during the current period		49	1
Less: volumes loaded during the current period and in transit at the end of the period		(40)	—
Total volumes recognized in the current period		581	14

Net income (loss) attributable to common stockholders


	Three Months Ended March 31,
(in millions, except per share data)		2022		2021		Variance
Net income (loss) attributable to common stockholders		$	(865)	$	393	$	(1,258)
Net income (loss) per share attributable to common stockholders—basic		(3.41)		1.56		(4.97)
Net income (loss) per share attributable to common stockholders—diluted		(3.41)		1.54		(4.95)

Our net loss attributable to common stockholders ~~decreased by $526~~was $865 million and $508 million during the three and six months ended June 30, 2021, respectively, from the comparable periods in 2020, primarily as a result of a $472 million and $886 million increase in derivative-related after-tax losses attributable to common stockholders for the three and six months ended June 30, 2021, respectively. The derivative-related losses in the three and six months ended June 30, 2021 were mainly the result of $674 million and $748 million, respectively, of pre-tax derivative losses, primarily on our commodity derivatives as a result of unfavorable shifts in international forward commodity curves. Additionally, during the three months ended ~~June 30, 2021~~March 31, 2022, compared to the comparable period in 2020, margins declined due to the non-recurrence, during the three months ended June 30, 2021, of accelerated revenues recognized from LNG cargoes for which customers notified us that they would not take delivery, which were partially offset by increased revenue on increased volume of LNG delivered. During the six months ended June 30, 2021, the decrease in net income attributable to common stockholders of $393 million for the three months ended March 31, 2021. The $1.3 billion decrease was primarily due to an increase in derivative losses from changes in ~~derivatives~~fair value and settlements of $3.5 billion (pre-tax and excluding the impact of non-controlling interest) between the periods, as further described below, and lower contribution from certain portfolio optimization activities. This impact was partially offset by ~~increased commodity margins per MMBtu~~increases in gross margin on ~~volumes~~LNG delivered ~~due to both increased revenue~~ per MMBtu and, ~~volumes~~to a lesser extent, an increase in volume delivered during the three months ended March 31, 2022 from the comparable period in 2021, as well as ~~higher than normal contributions from LNG and natural gas portfolio optimization activities due to significant volatility~~a decrease in ~~LNG and natural gas markets during~~ the six months ended June 30, 2021. This was partially offset by the non-recurrence, during the six months ended June 30, 2021, of accelerated revenues recognized from LNG cargoes for which customers notified us that they would not take delivery.income tax provision.

~~We enter into~~Substantially all derivative losses relate to the use of commodity derivative instruments indexed to ~~manage~~international LNG prices, primarily related to our IPM agreements. While operationally we utilize commodity derivatives to mitigate price volatility for commodities procured or sold over a period of time, as a result of significant appreciation in forward international LNG commodity curves during the three months ended March 31, 2022, we recognized $3.1 billion of non-cash unfavorable changes in fair value attributed to positions indexed to such prices (pre-tax and excluding the impact of non-controlling interest).

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Derivative instruments, which in addition to managing exposure to ~~(1) changing interest rates, (2)~~ commodity-related marketing and price risks ~~including those associated with our IPM transactions,~~are utilized to manage exposure to changing interest rates and ~~(3)~~ foreign exchange ~~volatility. Derivative instruments~~volatility, are reported at fair value on our Consolidated Financial Statements. ~~In some cases,~~For commodity derivative instruments related to our IPM agreements, the underlying transactions being economically hedged are accounted for under the accrual method of accounting, whereby revenues and expenses are recognized only upon delivery, receipt or realization of the underlying transaction. Because 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, use of derivative instruments may ~~increase the~~result in continued volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant ~~factors.~~factors, notwithstanding the operational intent to mitigate risk exposure over time.

Revenues


		Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Change		2021		2020		Change			(in millions)	2022		2021		Variance
LNG revenues	LNG revenues	$	2,913	$	2,295	$	618	$	5,912	$	4,863	$	1,049		LNG revenues	$	7,340	$	2,999	$	4,341
Regasification revenues	Regasification revenues	67		68		(1)		134		135		(1)			Regasification revenues	68		67		1
Other revenues	Other revenues	37		39		(2)		61		113		(52)			Other revenues	76		24		52

Total revenues	Total revenues	$	3,017	$	2,402	$	615	$	6,107	$	5,111	$	996		Total revenues	$	7,484	$	3,090	$	4,394

Total revenues increased during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 from the comparable ~~periods~~period in ~~2020,~~2021, primarily as a result of increased revenues per MMBtu and, to a lesser extent, from higher volume of LNG delivered between the ~~periods due to the non-recurrence of notification by our customers to not take delivery of scheduled LNG during the three and six months ended June 30, 2021.~~periods. Revenues per MMBtu of LNG ~~was~~were higher due to appreciation in international LNG prices resulting in improved market prices recognized by our integrated marketing function, ~~and~~as well as increases in Henry Hub prices. The volume of LNG delivered between the periods increased primarily as a result of ~~variable fees that are received in addition to fixed fees when the customers take delivery~~production from Train 3 of the ~~cargo as opposed to exercising their contractual right to not take delivery. During~~CCL Project and Train 6 of the ~~three~~SPL Project, which achieved substantial completion on March 26, 2021 and six months ended June 30, 2020, we recognized $708 million and $761 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $458 million would have been recognized subsequent to June 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended June 30, 2020 and six months ended June 30, 2021 excluded $53 million and $38 million, respectively, that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with theFebruary 4, 2022, respectively.

~~customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and six months ended June 30, 2021.~~

Prior to substantial completion of a Train, amounts received from the sale of commissioning cargoes from that Train are offset against LNG terminal construction-in-process, because these amounts are earned or loaded during the testing phase for the construction of that Train. During the three ~~and six~~ months ended ~~June 30,~~March 31, 2022 and 2021, we realized offsets to LNG terminal costs of ~~$36~~$204 millionand ~~$227~~$191 million, corresponding to 615 TBtu and 3125 TBtu respectively, that were related to the sale of commissioning cargoes from the Liquefaction Projects. ~~We did not realize any offsets to LNG terminal costs during the three and six months ended June 30, 2020.~~

~~Also included in~~ LNG revenues ~~are sales of certain unutilized natural gas procured for the liquefaction process and~~include gains and losses from derivative instruments, which include the realized value associated with a portion of derivative instruments that settle through physical delivery. We recognized offsets to revenues ~~(offsets to revenues)~~ of ~~$(340)~~$224 millionand ~~$61~~$39 million during the three months ended ~~June 30,~~March 31, 2022 and 2021, respectively, related to the gains and ~~2020, respectively,~~losses from derivative instruments primarily due to shifts in forward commodity curves. Also included in LNG revenues are sales of certain unutilized natural gas procured for the liquefaction process and ~~$(276)~~other revenues, which was $70 millionand ~~$273~~$104 million during the ~~six~~three months ended ~~June 30,~~March 31, 2022 and 2021, ~~and 2020, respectively, related to these transactions.~~respectively.

~~We expect our LNG revenues to increase in the future with Train 3~~

Table of ~~the CCL Project now fully operational and upon Train 6 of the SPL Project becoming operational.~~Contents

The following table presents the components of LNG revenues and the corresponding LNG volumes ~~sold:~~delivered:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended March 31,
		2021		2020		2021		2020				2022		2021
LNG revenues (in millions):	LNG revenues (in millions):									LNG revenues (in millions):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	LNG from the Liquefaction Projects sold under third party long-term agreements (1)	$	2,482	$	1,244	$	4,801	$	3,151	LNG from the Liquefaction Projects sold under third party long-term agreements (1)		$	4,138	$	2,319
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	683		150		1,202		475		LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements		3,098		519
LNG procured from third parties	LNG procured from third parties	88		132		185		203		LNG procured from third parties		258		96
LNG revenues associated with cargoes not delivered per customer notification (2)		—		708		—		761
Other revenues and net derivative gains (losses)		(340)		61		(276)		273

Net derivative losses										Net derivative losses		(224)		(39)
Other revenues										Other revenues		70		104
Total LNG revenues	Total LNG revenues	$	2,913	$	2,295	$	5,912	$	4,863	Total LNG revenues		$	7,340	$	2,999

Volumes delivered as LNG revenues (in TBtu):	Volumes delivered as LNG revenues (in TBtu):									Volumes delivered as LNG revenues (in TBtu):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	LNG from the Liquefaction Projects sold under third party long-term agreements (1)	403		253		784		619		LNG from the Liquefaction Projects sold under third party long-term agreements (1)		470		381
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	105		52		166		145		LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements		111		61
LNG procured from third parties	LNG procured from third parties	14		34		28		48		LNG procured from third parties		11		14
Total volumes delivered as LNG revenues	Total volumes delivered as LNG revenues	522		339		978		812		Total volumes delivered as LNG revenues		592		456

(1)Long-term agreements include agreements with an initial tenure of 12 months or more.

~~(2) LNG revenues include revenues with no corresponding volumes due to revenues attributable to LNG cargoes for which customers notified us that they would not take delivery.~~

Operating costs and expenses


		Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Change		2021		2020		Change			(in millions)	2022		2021		Variance
Cost of sales	Cost of sales	$	2,154	$	803	$	1,351	$	3,540	$	1,527	$	2,013		Cost of sales	$	7,336	$	1,386	$	5,950

Operating and maintenance expense	Operating and maintenance expense	385		355		30		707		671		36			Operating and maintenance expense	389		322		67
Development expense	Development expense	2		1		1		3		5		(2)			Development expense	5		1		4
Selling, general and administrative expense	Selling, general and administrative expense	73		73		—		154		154		—			Selling, general and administrative expense	96		81		15
Depreciation and amortization expense	Depreciation and amortization expense	258		233		25		494		466		28			Depreciation and amortization expense	271		236		35

Impairment expense and loss (gain) on disposal of assets		(1)		—		(1)		(1)		5		(6)

Total operating costs and expenses	Total operating costs and expenses	$	2,871	$	1,465	$	1,406	$	4,897	$	2,828	$	2,069		Total operating costs and expenses	$	8,097	$	2,026	$	6,071

Our total operating costs and expenses increased during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 from the comparable ~~periods~~period in ~~2020,~~2021, primarily as a result of increased cost of sales.

Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Projects, to the extent those costs are not utilized for the commissioning process. Cost of sales increased during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 from the comparable ~~2020 periods,~~2021 period, primarily due to ~~increased pricing of natural gas feedstock and increased volume of LNG produced, as well as~~ unfavorable changes in our commodity derivatives to secure natural gas feedstock for the Liquefaction Projects, which was driven by unfavorable shifts in international forward commodity ~~curves. Partially offsetting these increases were decreases in net~~curves, as discussed above under Net income (loss) attributable to common stockholders, as well as increased pricing of natural gas feedstock as a result of higher U.S. natural gas prices and, to a lesser extent, from increased volume of LNG delivered. Cost of sales also includes costs associated with the sale of certain unutilized natural gas procured for the liquefaction process and a portion of derivative instruments that settle through physical ~~delivery. Cost of sales also includes port and canal fees,~~delivery, variable transportation and storage costs, ~~net of margins from the sale of natural gas procured for the liquefaction process~~port and canal fees and other costs to convert natural gas into LNG.

Operating and maintenance expense primarily includes costs associated with operating and maintaining the Liquefaction Projects. During the three months ended March 31, 2022, operating and maintenance expense increased from the comparable period in 2021, primarily due to increased natural gas transportation and storage capacity demand charges, generally as a result of additional Trains that were in operation between the periods. Operating and maintenance expense also includes third party service and maintenance, payroll and benefit costs, insurance, regulatory costs and other operating costs.

Depreciation and amortization expense increased during the three months ended March 31, 2022 from the comparable period in 2021 as a result of commencing operations of Train 3 of the CCL Project in March 2021 and Train 6 of the SPL Project in February 2022.

We expect our operating costs and expenses to generally increase ~~in the future upon~~as Train 6 of the SPL Project ~~achieving~~achieved substantial completion on February 4, 2022, although we expect certain costs will not proportionally increase with the number of operational Trains as cost efficiencies will be realized.

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Other expense ~~(income)~~


		Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Change		2021		2020		Change			(in millions)	2022		2021		Variance
Interest expense, net of capitalized interest	Interest expense, net of capitalized interest	$	368	$	407	$	(39)	$	724	$	819	$	(95)		Interest expense, net of capitalized interest	$	349	$	356	$	(7)
Loss on modification or extinguishment of debt	Loss on modification or extinguishment of debt	4		43		(39)		59		44		15			Loss on modification or extinguishment of debt	18		55		(37)
Interest rate derivative loss, net	Interest rate derivative loss, net	2		25		(23)		1		233		(232)			Interest rate derivative loss, net	(3)		(1)		(2)
Other income, net		(4)		(5)		1		(10)		(14)		4
Other expense, net															Other expense, net	(5)		(6)		1
Total other expense	Total other expense	$	370	$	470	$	(100)	$	774	$	1,082	$	(308)		Total other expense	$	359	$	404	$	(45)

Interest expense, net of capitalized interest, decreased during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 from the comparable ~~2020 periods~~2021 period as a result of lower interest costs as a result of refinancing higher cost ~~debt.~~debt and repayment of debt in accordance with our capital allocation plan, partially offset by the portion of total interest costs that was eligible for capitalization due to the completion of construction of Train 3 of the CCL Project in March 2021 and Train 6 of the SPL Project in February 2022. During the three months ended ~~June 30,~~March 31, 2022 and 2021, ~~and 2020,~~ we incurred ~~$401~~$372 million and ~~$469~~$417 million of total interest cost, respectively, of which we capitalized ~~$33~~$23 million and $62 million, respectively, which was primarily related to interest costs incurred for the construction of the Liquefaction Projects. During the six months ended June 30, 2021 and 2020, we incurred $818 million and $940 million of total interest cost, respectively, of which we capitalized $94 million and $121$61 million, respectively, which was primarily related to interest costs incurred for the construction of the Liquefaction Projects.

Loss on modification or extinguishment of debt decreased during the three months ended ~~June 30, 2021 and increased during the six months ended June 30, 2021~~March 31, 2022 from the ~~respective~~ comparable ~~periods~~period in ~~2020. During the three months ended June 30,~~ 2021 we recognized $4 million of debt extinguishment costs relating to the termination of the Cheniere Term Loan Facility and in the six months ended June 30, 2021, we further recognized $54 million of debt extinguishment costs relating to the payment of early redemption fees and premiums and write off of unamortized debt issuance costs with the redemption of the 2025 CQP Senior Notes. Loss on modification or extinguishment of debt recognized in 2020 was primarily attributable to $43 million of debt extinguishment costs relating to the payment of early redemption fees and write off of unamortized debt premiums and issuance costs associated with the 5.625% Senior Secured Notes due 2021 (“2021 SPL Senior Notes”).

~~Interest rate derivative loss, net decreased during the three and six months ended June 30, 2021 compared to the comparable 2020 periods, primarily~~ due to a ~~favorable shift in the long-term forward LIBOR curve~~lower amount of debt that was paid down prior to their scheduled maturities between the periods, as further described in Liquidity and ~~the settlement~~Capital Resources—Sources and Uses of ~~certain outstanding derivatives in August 2020.~~Cash—Financing Cash Flows.

Income tax provision (benefit)


		Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended March 31,
(in millions)	(in millions)	2021			2020			Change		2021			2020			Change			(in millions)	2022			2021			Variance
Income (loss) before income taxes and non-controlling interest	Income (loss) before income taxes and non-controlling interest	$	(224)		$	467		$	(691)	$	436		$	1,201		$	(765)		Income (loss) before income taxes and non-controlling interest	$	(972)		$	660		$	(1,632)
Income tax provision (benefit)	Income tax provision (benefit)	(93)			63			(156)		(4)			194			(198)			Income tax provision (benefit)	$	(191)		$	89		$	(280)
Effective tax rate	Effective tax rate	41.5		%	13.5		%			(0.9)		%	16.2		%				Effective tax rate	19.7		%	13.5		%	6.2		%

~~The~~We recorded an income tax benefit of $191 million and income tax provision of $89 million during the three months ended March 31, 2022 and 2021, respectively.

Our effective tax ~~rates~~rate of 19.7% for the three ~~and six~~ months ended ~~June 30, 2021 were 41.5% and (0.9)%, respectively, and do not bear a customary relationship~~March 31, 2022 corresponds to ~~statutory~~an income tax ~~rates due to a combination of factors including income allocated to non-controlling interest that is not taxable to Cheniere and a $58 million discrete tax~~ benefit ~~related to releasing a portion of our valuation allowance caused by a change in tax law allowing for indefinite Louisiana net operating loss (“NOL”) carryover. The effective tax rates~~recorded for the ~~three~~period and ~~six months ended June 30, 2020 were 13.5% and 16.2%, respectively, which were~~was lower than the ~~21% federal~~ statutory income tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere partially offset by ~~a $38 million discrete~~ tax ~~expense~~benefits related to ~~an internal restructuring.~~stock-based compensation awards that vested in the quarter. Our effective tax rate ~~may continue~~of 13.5% for the three months ended March 31, 2021 corresponds to ~~experience volatility~~an income tax provision recorded for the period and was lower than the statutory income tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere.

Our effective tax rate is subject to variation prospectively due to variability in our pre-tax and taxable earnings and the proportion of such earnings attributable to non-controlling interests.

Net income attributable to non-controlling interest


		Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Change		2021		2020		Change			(in millions)	2022		2021		Variance
Net income attributable to non-controlling interest	Net income attributable to non-controlling interest	$	198	$	207	$	(9)	$	376	$	435	$	(59)		Net income attributable to non-controlling interest	$	84	$	178	$	(94)

Net income attributable to non-controlling interest decreased during the three ~~and six~~ months ended ~~June 30, 2021~~March 31, 2022 from the three ~~and six~~ months ended ~~June 30, 2020~~March 31, 2021 primarily due to aan decrease in consolidated net income recognized by ~~Cheniere Partners,~~CQP, which decreased from ~~$406~~net income of $347 million in the three months ended ~~June 30, 2020~~March 31, 2021 to ~~$395~~$159 million in the three months ended ~~June 30, 2021 and decreased from $841 million in~~March 31, 2022.

During the ~~six~~three months ended ~~June 30, 2020~~March 31, 2022, in fulfillment of a prior commitment to ~~$742~~collateralize financing for Train 6 of the SPL Project, Cheniere provided to SPL certain SPAs aggregating approximately 21 million tonnes of LNG to be delivered between 2023 and 2035 and an IPM agreement to purchase 140,000 MMBtu per day of natural gas for a term of

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approximately 15 years beginning in early 2023. As a result, net income attributable to non-controlling interest will be impacted in future periods as volumes are delivered under the ~~six months ended June 30, 2021.~~transferred contracts and by unrealized gains and losses on the IPM agreement, which is accounted for as a derivative.

Liquidity and Capital Resources

~~Although results are consolidated for financial reporting, SPL, Cheniere Partners, CCH Group~~The following information describes our ability to generate and ~~Cheniere operate with independent capital structures. Our capital~~obtain adequate amounts of cash to meet our requirements ~~include capital~~in the short term and ~~investment expenditures, repayment of long-term debt and repurchase of~~the long term. In the short term, we expect to meet our ~~shares. We expect the~~ cash ~~needs for at least the next twelve months will be met for each of these independent capital structures as follows:~~

•~~SPL through~~requirements using operating cash flows ~~project debt~~ and ~~borrowings~~available liquidity, consisting of cash and ~~equity contributions from Cheniere Partners;~~

•~~Cheniere Partners through~~cash equivalents, restricted cash and cash equivalents and available commitments under our credit facilities. In the long term, we expect to meet our cash requirements using operating cash flows ~~from SPLNG, SPL~~ and ~~CTPL, debt or equity offerings and borrowings;~~

•~~CCH Group through operating cash flows from CCL and CCP, project debt and borrowings and equity contributions from Cheniere; and~~

•~~Cheniere through existing unrestricted cash,~~other future potential sources of liquidity, which may include debt and equity offerings by us or our ~~subsidiaries, operating cash flows, borrowings, services fees from our subsidiaries and distributions from our investment in Cheniere Partners.~~

subsidiaries. The ~~following~~ table below provides a summary of our available liquidity ~~position at June 30, 2021 and December 31, 2020~~ (in millions):.

June 30, December 31,
2021 2020
Cash and cash equivalents (1) $ 1,806 $ 1,628
Restricted cash designated for the following purposes:
SPL Project 65 97
CCL Project 122 70
Other 237 282
Available commitments under the following credit facilities:
$1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”) 804 787
CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”) 750 750
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) 907 767
$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”) 1,116 1,126
Cheniere Term Loan Facility — 372


	March 31, 2022
Cash and cash equivalents (1)	$	2,487
Restricted cash and cash equivalents designated for the following purposes:

SPL Project	136


CCL Project	50
Cash held by our subsidiaries that is restricted to Cheniere	233
Available commitments under our credit facilities (2):

$1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement	832
CQP Credit Facilities executed in 2019	750


$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)	924
$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”)	1,250

Total available commitments under our credit facilities	3,756

Total available liquidity	$	6,662

(1)Amounts presented include balances held by our consolidated variable interest entity, ~~(“VIE”), Cheniere Partners,~~CQP, as discussed in Note 8—7—Non-controlling Interest and Variable Interest Entity of our Notes to Consolidated Financial Statements. As of ~~both June 30, 2021 and December~~March 31, ~~2020,~~2022, assets of ~~Cheniere Partners,~~CQP, which are included in our Consolidated Balance Sheets, included $1.2 billion of cash and cash equivalents.

(2)

~~Sabine Pass LNG Terminal~~

~~Liquefaction Facilities~~

~~The SPL Project is one~~Available commitments represent total commitments less loans outstanding and letters of ~~the largest LNG production~~credit issued under each of our credit facilities in the world. Through Cheniere Partners, we are currently operating five Trains and two marine berths at the SPL Project, and are constructing one additional Train that is expected to be substantially completed in the first half of 2022, and a third marine berth. We have achieved substantial completion of the first five Trains of the SPL Project and commenced commercial operating activities for each Train at various times starting in May 2016. The following table summarizes the project completion and construction status of Train 6 of the SPL Project as of ~~June 30, 2021:~~


						~~SPL Train 6~~
~~Overall project completion percentage~~						~~89.6%~~
~~Completion percentage of:~~
~~Engineering~~						~~99.7%~~
~~Procurement~~						~~99.9%~~
~~Subcontract work~~						~~70.2%~~
~~Construction~~						~~79.3%~~
~~Date of expected substantial completion~~						~~1H 2022~~

~~The DOE has issued three orders authorizing the export of domestically produced LNG by vessel from the Sabine Pass LNG terminal to FTA countries and non-FTA countries through December~~March 31, ~~2050, up to a combined total equivalent of approximately 1,509.3 Bcf/yr (approximately 30 mtpa) of natural gas.~~

In December 2020, the DOE announced a new policy in which it would no longer issue short-term export authorizations separately from long-term authorizations. Accordingly, the DOE amended each of SPL’s long-term authorizations to include short-term export authority, and vacated the short-term orders.

An application was filed in September 2019 seeking authorization to make additional exports from the SPL Project to FTA countries for a 25-year term and to non-FTA countries for a 20-year term in an amount up to the equivalent of approximately 153 Bcf/yr of natural gas, for a total SPL Project export capacity of approximately 1,662 Bcf/yr. The terms of the authorizations are requested to commence on the date of first commercial export from the SPL Project of the volumes contemplated in the application. In April 2020, the DOE issued an order authorizing SPL to export to FTA countries related to this application, for which the term was subsequently extended through December 31, 2050, but has not yet issued an order authorizing SPL to export to non-FTA countries for the corresponding LNG volume. A corresponding application for

authorization to increase the total LNG production capacity of the SPL Project from the currently authorized level to approximately 1,662 Bcf/yr was also submitted to the FERC and is currently pending.

~~Customers~~

SPL has entered into fixed price long-term SPAs generally with terms of 20 years (plus extension rights) and with a weighted average remaining contract length of approximately 17 years (plus extension rights) for Trains 1 through 6 of the SPL Project. Under these SPAs, the customers will purchase LNG from SPL for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG generally equal to approximately 115% of Henry Hub. The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under SPL’s SPAs. We refer to the fee component that is applicable only in connection with LNG cargo deliveries as the variable fee component of the price under SPL’s SPAs. The variable fees under SPL’s SPAs were generally sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation and liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery of a specified Train.

In aggregate, the annual fixed fee portion to be paid by the third-party SPA customers is approximately $2.9 billion for Trains 1 through 5. After giving effect to an SPA that Cheniere has committed to provide to SPL and upon the date of first commercial delivery of Train 6, the annual fixed fee portion to be paid by the third-party SPA customers is expected to increase to at least $3.3 billion.

~~In addition, Cheniere Marketing has an agreement with SPL to purchase, at Cheniere Marketing’s option, any LNG produced by SPL in excess of that required for other customers.~~2022. See ~~Marketing~~Note 9—Debt ~~section~~of our Notes to Consolidated Financial Statements for additional information ~~regarding agreements entered into by Cheniere Marketing.~~on our credit facilities and other debt instruments.

~~Natural Gas Transportation, Storage~~Our liquidity position subsequent to March 31, 2022 is driven by future sources of liquidity and ~~Supply~~future cash requirements. Future sources of liquidity are expected to be composed of (1) cash receipts from executed contracts, under which we are contractually entitled to future consideration, and (2) additional sources of liquidity, from which we expect to receive cash although the cash is not underpinned by executed contracts. Future cash requirements are expected to be composed of (1) cash payments under executed contracts, under which we are contractually obligated to make payments, and (2) additional cash requirements, under which we expect to make payments although we are not contractually obligated to make the payments under executed contracts.

~~To ensure~~Although material sources of liquidity and material cash requirements are presented below from a consolidated standpoint, SPL, CQP, CCH and Cheniere operate with independent capital structures. Certain restrictions under debt and equity instruments executed by our subsidiaries limit each entity’s ability to distribute cash, including the following:

•SPL and CCH are 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 ~~able to transport adequate natural gas feedstock~~restricted to the ~~Sabine Pass LNG terminal, it has entered into transportation precedent~~payment of liabilities related to the Liquefaction Projects and other ~~agreements~~restricted payments. The majority of the cash held by SPL and CCH that is restricted to ~~secure firm pipeline transportation capacity~~Cheniere relates to advance funding for operation and construction of the Liquefaction Projects;

•CQP is required under its partnership agreement to distribute to unitholders all available cash on hand at the end of a quarter less the amount of any reserves established by its general partner. Beginning with ~~CTPL~~the distribution related to the first quarter of 2022, the quarterly distributions by CQP are expected to be comprised of a base amount plus a variable amount equal to the remaining available cash per unit, which takes into consideration, among other things,

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amounts reserved for annual debt repayment and ~~third-party pipeline companies. SPL has entered into firm storage services agreements~~capital allocation goals, anticipated capital expenditures to be funded with ~~third parties~~cash, and cash reserves to ~~assist in managing variability in natural gas needs~~provide for the proper conduct of CQP’s business.

•Our 48.6% limited partner interest, 100% general partner interest and incentive distribution rights in CQP limit our right to receive cash held by CQP to the amounts specified by the provisions of CQP’s partnership agreement; and

•SPL, ~~Project. SPL has also entered into enabling~~CQP and CCH are restricted by affirmative and negative covenants included in certain of their debt agreements ~~and long-term natural gas supply contracts with third parties~~ in ~~order~~their ability to secure natural gas feedstock for the SPL Project. As of June 30, 2021, SPL had secured up to approximately 5,025 TBtu of natural gas feedstock through long-term and short-term natural gas supply contracts with remaining terms that range up to 10 years, a portion of which is subject to conditions precedent.make certain payments, including distributions, unless specific requirements are satisfied.

~~Construction~~

~~SPL entered into lump sum turnkey contracts with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for~~Notwithstanding the engineering, procurement and construction of Trains 1 through 6 of the SPL Project, under which Bechtel charges a lump sum for all work performed and generally bears project cost, schedule and performance risks unless certain specified events occur, in which case Bechtel may cause SPL to enter into a change order, or SPL agrees with Bechtel to a change order.

The total contract price of the EPC contract for Train 6 of the SPL Project is approximately $2.5 billion, including estimated costs for the third marine berth that is currently under construction. As of June 30, 2021,restrictions noted above, we ~~have incurred $2.1 billion under this contract.~~

~~Regasification Facilities~~

The Sabine Pass LNG terminal has operational regasification capacity of approximately 4 Bcf/d and aggregate LNG storage capacity of approximately 17 Bcfe. Approximately 2 Bcf/d of the regasification capacity at the Sabine Pass LNG terminal has been reserved under two long-term third-party TUAs, under which SPLNG’s customers are required to pay fixed monthly fees, whether or not they use the LNG terminal. Each of Total Gas & Power North America, Inc. (“Total”) and

Chevron U.S.A. Inc. (“Chevron”) has reserved approximately 1 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually, prior to inflation adjustments, for 20 years that commenced in 2009. Total S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions, and Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.

The remaining approximately 2 Bcf/d of capacity has been reserved under a TUA by SPL. SPL is obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million annually, prior to inflation adjustments, continuing until at least May 2036. SPL entered into a partial TUA assignment agreement with Total, whereby upon substantial completion of Train 5 of the SPL Project, SPL gained access to substantially all of Total’s capacity and other services provided under Total’s TUA with SPLNG. This agreement provides SPL with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to provide increased flexibility in managing LNG cargo loading and unloading activity, permit SPL to more flexibly manage its LNG storage capacity and accommodate the development of Train 6. Notwithstanding any arrangements between Total and SPL, payments required to be made by Total to SPLNG will continue to be made by Total to SPLNG in accordance with its TUA. During each of the three months ended June 30, 2021 and 2020, SPL recorded $33 million, and during each of the six months ended June 30, 2021 and 2020, SPL recorded $65 million, as operating and maintenance expense under this partial TUA assignment agreement.

~~Under each of these TUAs, SPLNG is entitled to retain 2% of the LNG delivered to the Sabine Pass LNG terminal.~~

~~Capital Resources~~

We currently expect that SPL’s capital resources requirements with respect to the SPL Project will be financed through project debt and borrowings, cash flows under the SPAs and equity contributions from Cheniere Partners. We believe that ~~with~~sufficient flexibility exists within the ~~net proceeds of borrowings, available commitments under the 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities, cash flows from operations and equity contributions from~~ Cheniere ~~Partners~~, ~~SPL will have adequate financial resources available~~complex to enable each independent capital structure to meet its currently anticipated ~~capital, operating~~cash requirements. The sources of liquidity at SPL, CQP and ~~debt service~~CCH primarily fund the cash requirements ~~with respect to Trains 1 through 6~~ of the ~~SPL Project. Additionally, SPLNG generates~~respective entity, and any remaining liquidity not subject to restriction, as supplemented by liquidity provided by Cheniere Marketing, is available to enable Cheniere to meet its cash ~~flows from the TUAs, as discussed above.~~

The following table provides a summary of our capital resources from borrowings and available commitments for the Sabine Pass LNG terminal, excluding equity contributions to our subsidiaries and cash flows from operations (as described in ~~Sources and Uses of Cash), at June 30, 2021 and December 31, 2020 (in millions):~~

June 30, December 31,
2021 2020
Senior notes (1) $ 17,750 $ 17,750
Letters of credit issued (2) 396 413
Available commitments under credit facilities (2) 1,554 1,537
Total capital resources from borrowings and available commitments (3) $ 19,700 $ 19,700

(1) Includes SPL’s 6.25% Senior Secured Notes due 2022, 5.625% Senior Secured Notes due 2023, 5.75% Senior Secured Notes due 2024, 5.625% Senior Secured Notes due 2025, 5.875% Senior Secured Notes due 2026 (the “2026 SPL Senior Notes”), 5.00% Senior Secured Notes due 2027 (the “2027 SPL Senior Notes”), 4.200% Senior Secured Notes due 2028 (the “2028 SPL Senior Notes”), 4.500% Senior Secured Notes due 2030 (the “2030 SPL Senior Notes”) and 5.00% Senior Secured Notes due 2037 (the “2037 SPL Senior Notes”) (collectively, the “SPL Senior Notes”), as well as the 2025 CQP Senior Notes, $1.1 billion of 5.625% Senior Notes due 2026 (the “2026 CQP Senior Notes”), the 4.500% Senior Notes due 2029 (the “2029 CQP Senior Notes”) and the 2031 CQP Senior Notes (collectively, the “CQP Senior Notes”).

~~(2) Consists of 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities.~~

~~(3) Does not include equity contributions that may be available from Cheniere’s borrowings and available cash and cash equivalents.~~requirements.

~~SPL Senior Notes~~

The SPL Senior Notes are governed by a common indenture (the “SPL Indenture”) and the terms of the 2037 SPL Senior Notes are governed by a separate indenture (the “2037 SPL Senior Notes Indenture”). Both the SPL Indenture and the 2037 SPL Senior Notes Indenture contain terms and events of default and certain covenants that, among other things, limit SPL’s ability and the ability of SPL’s restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of SPL’s restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of SPL’s assets and enter into certain LNG sales contracts. Subject to permitted liens, the SPL Senior Notes are secured on a ~~pari passu~~ first-priority basis by a security interest in all of the membership interests in SPL and substantially all of SPL’s assets. SPL may not make any distributions until, among other requirements, deposits are made into debt service reserve accounts as required and a debt service coverage ratio test of 1.25:1.00 is satisfied.

At any time prior to three months before the respective dates of maturity for each series of the SPL Senior Notes (except for the 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes, 2030 SPL Senior Notes and 2037 SPL Senior Notes, in which case the time period is six months before the respective dates of maturity), SPL may redeem all or part of such series of the SPL Senior Notes at a redemption price equal to the ‘make-whole’ price (except for the 2037 SPL Senior Notes, in which case the redemption price is equal to the “optional redemption” price) set forth in the respective indentures governing the SPL Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. SPL may also, at any time within three months of the respective maturity dates for each series of the SPL Senior Notes (except for the 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes, 2030 SPL Senior Notes and 2037 SPL Senior Notes, in which case the time period is within six months of the respective dates of maturity), redeem all or part of such series of the SPL Senior Notes at a redemption price equal to 100% of the principal amount of such series of the SPL Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

SPL may incur additional indebtedness in the future, including by issuing additional notes, and such indebtedness could be at higher interest rates and have different maturity dates and more restrictive covenants than the current outstanding indebtedness of SPL, including the SPL Senior Notes and the 2020 SPL Working Capital Facility. Semi-annual principal payments for the 2037 SPL Senior Notes are due on March 15 and September 15 of each year beginning September 15, 2025 and are fully amortizing according to a fixed sculpted amortization schedule.

During 2021, SPL entered into a series of note purchase agreements for the sale of approximately $347 million aggregate principal amount of the 2037 SPL Private Placement Senior Secured Notes on a private placement basis. The 2037 SPL Private Placement Senior Secured Notes are expected to be issued in the second half of 2021, subject to customary closing conditions, and the net proceeds will be used to strategically refinance a portion of SPL’s outstanding 6.25% SPL Senior Secured Notes due 2022 and pay related fees, costs and expenses. The 2037 SPL Private Placement Senior Secured Notes will be fully amortizing, with a weighted average life of over 10 years.

~~2020 SPL Working Capital Facility~~

In March 2020, SPL entered into the 2020 SPL Working Capital Facility with aggregate commitments of $1.2 billion, which replaced the $1.2 billion Amended and Restated SPL Working Capital Facility (the “2015 SPL Working Capital Facility”). The 2020 SPL Working Capital Facility is intended to be used for loans to SPL, swing line loans to SPL and the issuance of letters of credit on behalf of SPL, primarily for (1) the refinancing of the 2015 SPL Working Capital Facility, (2) fees and expenses related to the 2020 SPL Working Capital Facility, (3) SPL and its future subsidiaries’ gas purchase obligations and (4) SPL and certain of its future subsidiaries’ general corporate purposes. SPL may, from time to time, request increases in the commitments under the 2020 SPL Working Capital Facility of up to $800 million. As of June 30, 2021 and December 31, 2020, SPL had $804 million and $787 million of available commitments and $396 million and $413 million aggregate amount of issued letters of credit, respectively. As of both June 30, 2021 and December 31, 2020, SPL had no outstanding borrowings under the 2020 SPL Working Capital Facility.

The 2020 SPL Working Capital Facility matures on March 19, 2025, but may be extended with consent of the lenders. The 2020 SPL Working Capital Facility provides for mandatory prepayments under customary circumstances.

The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, satisfaction of a 12-month forward-looking and backward-looking 1.25:1.00 debt service reserve ratio test. The obligations of SPL under the 2020 SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as a pledge of all of the membership interests in SPL and certain future subsidiaries of SPL on a ~~pari passu~~ ~~basis by a first priority lien with the SPL Senior Notes.~~

~~Cheniere Partners~~

~~CQP Senior Notes~~

The CQP Senior Notes are jointly and severally guaranteed by each of Cheniere Partners’ subsidiaries other than SPL and, subject to certain conditions governing its guarantee, Sabine Pass LP (each a “Guarantor” and collectively, the “CQP Guarantors”). The CQP Senior Notes are governed by the same base indenture (the “CQP Base Indenture”). The 2026 CQP Senior Notes are further governed by the Second Supplemental Indenture, the 2029 CQP Senior Notes are further governed by the Third Supplemental Indenture and the 2031 CQP Senior Notes are further governed by the Fifth Supplemental Indenture. The indentures governing the CQP Senior Notes contain terms and events of default and certain covenants that, among other things, limit the ability of Cheniere Partners and the CQP Guarantors to incur liens and sell assets, enter into transactions with affiliates, enter into sale-leaseback transactions and consolidate, merge or sell, lease or otherwise dispose of all or substantially all of the applicable entity’s properties or assets.

At any time prior to October 1, 2021 for the 2026 CQP Senior Notes, October 1, 2024 for the 2029 CQP Senior Notes and March 1, 2026 for the 2031 CQP Senior Notes, Cheniere Partners may redeem all or a part of the applicable CQP Senior Notes at a redemption price equal to 100% of the aggregate principal amount of the CQP Senior Notes redeemed, plus the “applicable premium” set forth in the respective indentures governing the CQP Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. In addition, at any time prior to October 1, 2021 for the 2026 CQP Senior Notes, October 1, 2024 for the 2029 CQP Senior Notes and March 1, 2024 for the 2031 CQP Senior Notes, Cheniere Partners may redeem up to 35% of the aggregate principal amount of the CQP Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 105.625% of the aggregate principal amount of the 2026 CQP Senior Notes, 104.5% of the aggregate principal amount of the 2029 CQP Senior Notes and 104.000% of the aggregate principal amount of the 2031 CQP Senior Notes redeemed, plus accrued and unpaid interest, if any, to the date of redemption. Cheniere Partners also may at any time on or after October 1, 2021 through the maturity date of October 1, 2026 for the 2026 CQP Senior Notes, October 1, 2024 through the maturity date of October 1, 2029 for the 2029 CQP Senior Notes and March 1, 2026 through the maturity date of March 1, 2031 for the 2031 CQP Senior Notes, redeem the CQP Senior Notes, in whole or in part, at the redemption prices set forth in the respective indentures governing the CQP Senior Notes.

The CQP Senior Notes are Cheniere Partners’ senior obligations, ranking equally in right of payment with Cheniere Partners’ other existing and future unsubordinated debt and senior to any of its future subordinated debt. In the event that the aggregate amount of Cheniere Partners’ secured indebtedness and the secured indebtedness of the CQP Guarantors (other than the CQP Senior Notes or any other series of notes issued under the CQP Base Indenture) outstanding at any one time exceeds the greater of (1) $1.5 billion and (2) 10% of net tangible assets, the CQP Senior Notes will be secured to the same extent as such obligations under the 2019 CQP Credit Facilities. The obligations under the 2019 CQP Credit Facilities are secured on a first-priority basis (subject to permitted encumbrances) with liens on substantially all the existing and future tangible and intangible assets and rights of Cheniere Partners and the CQP Guarantors and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities). The liens securing the CQP Senior Notes, if applicable, will be shared equally and ratably (subject to permitted liens) with the holders of other senior secured obligations, which include the 2019 CQP Credit Facilities obligations and any future additional senior secured debt obligations.

~~2019 CQP Credit Facilities~~

Cheniere Partners has a $750 million revolving credit facility under the 2019 CQP Credit Facilities. Borrowings under the 2019 CQP Credit Facilities will be used to fund the development and construction of Train 6 of the SPL Project and for general corporate purposes, subject to a sublimit, and the 2019 CQP Credit Facilities are also available for the issuance of letters of credit. As of both June 30, 2021 and December 31, 2020, Cheniere Partners had $750 million of available commitments and no letters of credit issued or loans outstanding under the 2019 CQP Credit Facilities.

The 2019 CQP Credit Facilities mature on May 29, 2024. Any outstanding balance may be repaid, in whole or in part, at any time without premium or penalty, except for interest rate breakage costs. The 2019 CQP Credit Facilities contain conditions precedent for extensions of credit, as well as customary affirmative and negative covenants, and limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions are satisfied.

The 2019 CQP Credit Facilities are unconditionally guaranteed and secured by a first priority lien (subject to permitted encumbrances) on substantially all of Cheniere Partners’ and the CQP Guarantors’ existing and future tangible and intangible assets and rights and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities).

~~Corpus Christi LNG Terminal~~

~~Liquefaction Facilities~~

We are currently operating three Trains and two marine berths at the CCL Project. We completed construction of Trains 1, 2 and 3 of the CCL Project and commenced commercial operating activities in February 2019, August 2019 and March 2021, respectively.

Separate from the CCH Group, we are also developing Corpus Christi Stage 3 through our subsidiary CCL Stage III, adjacent to the CCL Project. We received approval from FERC in November 2019 to site, construct and operate seven midscale Trains with an expected total production capacity of approximately 10 mtpa of LNG.

~~The following orders have been issued by the DOE authorizing the export of domestically produced LNG by vessel from the Corpus Christi LNG terminal:~~

•~~CCL Project—FTA countries and non-FTA countries through December 31, 2050, up to a combined total of the equivalent of 767 Bcf/yr (approximately 15 mtpa) of natural gas.~~

•~~Corpus Christi Stage 3—FTA countries and non-FTA countries through December 31, 2050 in an amount equivalent to 582.14 Bcf/yr (approximately 11 mtpa) of natural gas.~~

In December 2020, the DOE announced a new policy in which it would no longer issue short-term export authorizations separately from long-term authorizations. Accordingly, the DOE amended each of CCL’s long-term authorizations to include short-term export authority, and vacated the short-term orders.

An application was filed in September 2019 to authorize additional exports from the CCL Project to FTA countries for a 25-year term and to non-FTA countries for a 20-year term in an amount up to the equivalent of approximately 108 Bcf/yr of natural gas, for a total CCL Project export of 875.16 Bcf/yr. The terms of the authorizations are requested to commence on the date of first commercial export from the CCL Project of the volumes contemplated in the application. In April 2020, the DOE issued an order authorizing CCL to export to FTA countries related to this application, for which the term was subsequently extended through December 31, 2050, but has not yet issued an order authorizing CCL to export to non-FTA countries for the corresponding LNG volume. A corresponding application for authorization to increase the total LNG production capacity of the CCL Project from the currently authorized level to approximately 875.16 Bcf/yr was also submitted to the FERC and is currently pending.

~~Customers~~

CCL has entered into fixed price long-term SPAs generally with terms of 20 years (plus extension rights) and with a weighted average remaining contract length of approximately 18 years (plus extension rights) for Trains 1 through 3 of the CCL Project. Under these SPAs, the customers will purchase LNG from CCL on a free on board (“FOB”) basis for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG equal to approximately 115% of Henry Hub. The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under our SPAs. We refer to the fee component that is applicable only in

connection with LNG cargo deliveries as the variable fee component of the price under our SPAs. The variable fee under CCL’s SPAs entered into in connection with the development of the CCL Project was sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation and liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery for the applicable Train, as specified in each SPA.

~~In aggregate, the minimum annual fixed fee portion to be paid by the third-party SPA customers is approximately $1.8 billion for Trains 1 through 3.~~

In addition, Cheniere Marketing has agreements with CCL to purchase: (1) approximately 15 TBtu per annum of LNG with a term through 2043, (2) any LNG produced by CCL in excess of that required for other customers at Cheniere Marketing’s option and (3) approximately 44 TBtu of LNG with a maximum term up to 2026 associated with the IPM gas supply agreement between CCL and EOG Resources, Inc. See ~~Marketing~~ ~~section for additional information regarding agreements entered into by Cheniere Marketing.~~

~~Natural Gas Transportation, Storage and Supply~~

To ensure CCL is able to transport adequate natural gas feedstock to the Corpus Christi LNG terminal, it has entered into transportation precedent agreements to secure firm pipeline transportation capacity with CCP and certain third-party pipeline companies. CCL has entered into a firm storage services agreement with a third party to assist in managing variability in natural gas needs for the CCL Project. CCL has also entered into enabling agreements and long-term natural gas supply contracts with third parties, and will continue to enter into such agreements, in order to secure natural gas feedstock for the CCL Project. As of June 30, 2021, CCL had secured up to approximately 2,980 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to 10 years, a portion of which is subject to the achievement of certain project milestones and other conditions precedent.

CCL Stage III has also entered into long-term natural gas supply contracts with third parties, and anticipates continuing to enter into such agreements, in order to secure natural gas feedstock for Corpus Christi Stage 3. As of June 30, 2021, CCL Stage III had secured up to approximately 2,361 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to approximately 15 years, which is subject to the achievement of certain project milestones and other conditions precedent.

A portion of the natural gas feedstock transactions for CCL and CCL Stage III are IPM transactions, in which the natural gas producers are paid based on a global gas market price less a fixed liquefaction fee and certain costs incurred by us.

~~Construction~~

CCL entered into separate lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of Trains 1 through 3 of the CCL Project under which Bechtel charged a lump sum for all work performed and generally bore project cost, schedule and performance risks unless certain specified events occurred, in which case Bechtel may have caused CCL to enter into a change order, or CCL agreed with Bechtel to a change order.

~~Final Investment Decision for Corpus Christi Stage 3~~

FID for Corpus Christi Stage 3 will be subject to, among other things, entering into an EPC contract, obtaining additional commercial support for the project and securing the necessary financing arrangements.

~~Pipeline Facilities~~

In November 2019, the FERC authorized CCP to construct and operate the pipeline for Corpus Christi Stage 3. The pipeline will be designed to transport 1.5 Bcf/d of natural gas feedstock required by Corpus Christi Stage 3 from the existing regional natural gas pipeline grid.

~~Capital Resources~~

The following table provides a summary of the capital resources of the CCH Group from borrowings and available commitments for the CCL Project, excluding equity contributions from Cheniere, at June 30, 2021 and December 31, 2020 (in millions):

June 30, December 31,
2021 2020
Senior notes (1) $ 7,721 $ 7,721
Credit facilities outstanding balance (2) 2,627 2,767
Letters of credit issued (2) 293 293
Available commitments under credit facilities (2) 907 767
Total capital resources from borrowings and available commitments (3) $ 11,548 $ 11,548

(1) Includes CCH’s 7.000% Senior Secured Notes due 2024, 5.875% Senior Secured Notes due 2025, 5.125% Senior Secured Notes due 2027, 3.700% Senior Secured Notes due 2029, 4.80% Senior Secured Notes due 2039, 3.925% Senior Secured Notes due 2039 and 3.52% CCH Senior Secured Notes (collectively, the “CCH Senior Notes”).

~~(2) Includes CCH’s amended and restated credit facility (the “CCH Credit Facility”) and the CCH Working Capital Facility.~~

~~(3) Does not include equity contributions that may be available from Cheniere’s borrowings and available cash and cash equivalents.~~

~~CCH Senior Notes~~

The CCH Senior Notes are jointly and severally guaranteed by CCH’s subsidiaries, CCL, CCP and Corpus Christi Pipeline GP, LLC (each a “CCH Guarantor” and collectively, the “CCH Guarantors”). The indentures governing the CCH Senior Notes contain customary terms and events of default and certain covenants that, among other things, limit CCH’s ability and the ability of CCH’s restricted subsidiaries to: incur additional indebtedness or issue preferred stock; make certain investments or pay dividends or distributions on membership interests or subordinated indebtedness or purchase, redeem or retire membership interests; sell or transfer assets, including membership or partnership interests of CCH’s restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries to CCH or any of CCH’s restricted subsidiaries; incur liens; enter into transactions with affiliates; dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of the properties or assets of CCH and its restricted subsidiaries taken as a whole; or permit any CCH Guarantor to dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of its properties and assets. The covenants included in the respective indentures that govern the CCH Senior Notes are subject to a number of important limitations and exceptions.

The CCH Senior Notes are CCH’s senior secured obligations, ranking senior in right of payment to any and all of CCH’s future indebtedness that is subordinated to the CCH Senior Notes and equal in right of payment with CCH’s other existing and future indebtedness that is senior and secured by the same collateral securing the CCH Senior Notes. The CCH Senior Notes are secured by a first-priority security interest in substantially all of CCH’s and the CCH Guarantors’ assets.

At any time prior to six months before the respective dates of maturity for each of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes at a redemption price equal to the “make-whole” price set forth in the appropriate indenture, plus accrued and unpaid interest, if any, to the date of redemption. At any time within six months of the respective dates of maturity for each of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the CCH Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

~~CCH Credit Facility~~

CCH has total commitments under the CCH Credit Facility of $6.1 billion. The obligations of CCH under the CCH Credit Facility are secured by a first priority lien on substantially all of the assets of CCH and its subsidiaries and by a pledge by CCH HoldCo I of its limited liability company interests in CCH. As of both June 30, 2021 and December 31, 2020, CCH had no available commitments and $2.6 billion of loans outstanding under the CCH Credit Facility.

The CCH Credit Facility matures on June 30, 2024, with principal payments due quarterly commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following the completion of the CCL Project as defined in the common terms agreement and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train of the CCL Project to become operational is entitled to terminate its SPA for failure to achieve the date of first commercial delivery for that agreement. Scheduled repayments will be based upon a 19-year tailored amortization, commencing the first full quarter after the completion of Trains 1 through 3 and designed to achieve a minimum projected fixed debt service coverage ratio of 1.50:1.

Under the CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt. CCH is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, the completion of the construction of Trains 1 through 3 of the CCL Project, funding of a debt service reserve account equal to six months of debt service and achieving a historical debt service coverage ratio and fixed projected debt service coverage ratio of at least 1.25:1.00.

~~CCH Working Capital Facility~~

CCH has total commitments under the CCH Working Capital Facility of $1.2 billion. The CCH Working Capital Facility is intended to be used for loans to CCH (“CCH Working Capital Loans”) and the issuance of letters of credit on behalf of CCH for certain working capital requirements related to developing and operating the CCL Project and for related business purposes. Loans under the CCH Working Capital Facility are guaranteed by the CCH Guarantors. CCH may, from time to time, request increases in the commitments under the CCH Working Capital Facility of up to the maximum allowed for working capital under the Common Terms Agreement that was entered into concurrently with the CCH Credit Facility. As of June 30, 2021 and December 31, 2020, CCH had $907 million and $767 million of available commitments and zero and $140 million of loans outstanding under the CCH Working Capital Facility, respectively. CCH had $293 million aggregate amount of issued letters of credit under the CCH Working Capital Facility as of both June 30, 2021 and December 31, 2020.

The CCH Working Capital Facility matures on June 29, 2023, and CCH may prepay the CCH Working Capital Loans and loans made in connection with a draw upon any letter of credit (“CCH LC Loans”) at any time without premium or penalty upon three business days’ notice and may re-borrow at any time. CCH LC Loans have a term of up to one year. CCH is required to reduce the aggregate outstanding principal amount of all CCH Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The CCH Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of CCH under the CCH Working Capital Facility are secured by substantially all of the assets of CCH and the CCH Guarantors as well as all of the membership interests in CCH and each of the CCH Guarantors on a ~~pari passu~~ ~~basis with the CCH Senior Notes and the CCH Credit Facility.~~

~~Cheniere~~

~~Senior Notes~~

We have an aggregate principal amount of $2.0 billion of the 4.625% Senior Secured Notes due 2028 (the “2028 Cheniere Senior Notes”), the proceeds of which were used to prepay a portion of the outstanding indebtedness under the Cheniere Term Loan Facility and to pay related fees and expenses. The associated indentures (“Cheniere Indenture”) contain customary terms and events of default and certain covenants that, among other things, limit our ability to create liens or other encumbrances, enter into sale-leaseback transactions and merge or consolidate with other entities or sell all or substantially all of our assets. The Cheniere Indenture covenants are subject to a number of important limitations and exceptions.

At any time prior to October 15, 2023, we may redeem all or a part of the 2028 Cheniere Senior Notes at a redemption price equal to 100% of the aggregate principal amount thereof, plus the “applicable premium” and accrued and unpaid interest, if any, to but not including the date of redemption. We also may, at any time prior to October 15, 2023, redeem up to 40% of the aggregate principal amount of the 2028 Cheniere Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 104.625% of the aggregate principal amount of the notes being redeemed, plus accrued and unpaid interest, if any, to but not including, the date of redemption. At any time on or after October 15, 2023 through the maturity date of October 15, 2028, we may redeem all or part of the 2028 Cheniere Senior Notes at the redemption prices described in the Cheniere Indenture.

The 2028 Cheniere Senior Notes are our general senior obligations and rank senior in right of payment to all of our future obligations that are, by their terms, expressly subordinated in right of payment to the 2028 Cheniere Senior Notes and equally in right of payment with all of our other existing and future unsubordinated indebtedness. The 2028 Cheniere Senior Notes became unsecured in June 2021 concurrent with the repayment of all outstanding obligations under the Cheniere Term Loan Facility and may, in certain instances become secured in the future in connection with the incurrence of additional secured indebtedness by us. When required, the 2028 Cheniere Senior Notes will be secured on a first-priority basis by a lien on substantially all of our assets and equity interests in our direct subsidiaries (other than certain excluded subsidiaries), which liens rank ~~pari passu~~ with the liens securing the Cheniere Revolving Credit Facility. As of June 30, 2021, the 2028 Cheniere Senior Notes are not guaranteed by any of our subsidiaries. In the future, the 2028 Cheniere Senior Notes will be guaranteed by our subsidiaries who guarantee our other material indebtedness.

~~Convertible Notes~~

We have $625 million aggregate principal amount of 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”). We have the right, at our option, at any time after March 15, 2020, to redeem all or any part of the 2045 Cheniere Convertible Senior Notes at a redemption price equal to the accreted amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date. Prior to December 15, 2044, the 2045 Cheniere Convertible Senior Notes are convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes, which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).

~~We have the option to satisfy the conversion obligation for the 2045 Cheniere Convertible Senior Notes with cash, common stock or a combination thereof.~~

~~Cheniere Revolving Credit Facility~~

We have total commitments under the Cheniere Revolving Credit Facility of $1.25 billion. The Cheniere Revolving Credit Facility is intended to fund, through loans and letters of credit, equity capital contributions to CCH HoldCo II and its subsidiaries for the development of the CCL Project and, provided that certain conditions are met, for general corporate purposes. As of both June 30, 2021 and December 31, 2020, we had $1.1 billion of available commitments and $134 million and zero, respectively, of loans outstanding under the Cheniere Revolving Credit Facility. We had zero and $124 million aggregate amount of issued letters of credit under the Cheniere Revolving Credit Facility as of June 30, 2021 and December 31, 2020, respectively. In July 2021, the outstanding balance under the Cheniere Revolving Credit Facility was repaid.

The Cheniere Revolving Credit Facility matures on December 13, 2022 and contains representations, warranties and affirmative and negative covenants customary for companies like us with lenders of the type participating in the Cheniere Revolving Credit Facility that limit our ability to make restricted payments, including distributions, unless certain conditions are satisfied, as well as limitations on indebtedness, guarantees, hedging, liens, investments and affiliate transactions. Under the Cheniere Revolving Credit Facility, we are required to ensure that the sum of our unrestricted cash and the amount of undrawn commitments under the Cheniere Revolving Credit Facility is at least equal to the lesser of (1) 20% of the commitments under the Cheniere Revolving Credit Facility and (2) $200 million (the “Liquidity Covenant”). However, at any time that the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit under the Cheniere Revolving Credit Facility is greater than 30% of aggregate commitments under the Cheniere Revolving Credit Facility, the Liquidity Covenant will not apply and we will instead be governed by a quarterly non-consolidated leverage ratio covenant not to exceed 5.75:1.00 (the “Springing Leverage Covenant”).

The Cheniere Revolving Credit Facility is secured by a first priority security interest (subject to permitted liens and other customary exceptions) in substantially all of our assets, including our interests in our direct subsidiaries (excluding CCH HoldCo II and certain other subsidiaries).

~~Cash Receipts from Subsidiaries~~

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. As of June 30, 2021, we owned a 48.6% limited partner interest in Cheniere Partners in the form of 239.9 million common units. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. We are eligible to receive quarterly equity distributions from Cheniere Partners related to our ownership interests and our incentive distribution rights.

We also receive fees for providing management services to some of our subsidiaries. We received $57 million and $53 million in total service fees from these subsidiaries during the six months ended June 30, 2021 and 2020, respectively.

~~Share Repurchase Program~~

On June 3, 2019, we announced that our Board authorized a 3-year, $1.0 billion share repurchase program. During the six months ended June 30, 2020, we repurchased an aggregate of 2.9 million shares of our common stock for $155 million, for a weighted average price per share of $53.88. We did not make any repurchases during the three months ended June 30, 2021 and 2020 or the six months ended June 30, 2021. As of June 30, 2021, we had $596 million of the share repurchase program available. Under the share repurchase program, repurchases can be made from time to time using a variety of methods, which may include open market purchases, privately negotiated transactions or otherwise, all in accordance with the rules of the SEC and other applicable legal requirements. The timing and amount of any shares of our common stock that are repurchased under the share repurchase program will be determined by our management based on market conditions and other factors. The share repurchase program does not obligate us to acquire any particular amount of common stock, and may be modified, suspended or discontinued at any time or from time to time at our discretion.

~~Marketing~~

We market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. We have, and continue to develop, a portfolio of long-, medium- and short-term SPAs to transport and unload commercial LNG cargoes to locations worldwide. These volumes are expected to be primarily sourced by LNG produced by the Liquefaction Projects but supplemented by volumes procured from other locations worldwide, as needed. As of June 30, 2021, we have sold or have options to sell approximately 5,002 TBtu of LNG to be delivered to customers between 2021 and 2045, including volume from an SPA Cheniere Marketing has committed to provide to SPL. The cargoes have been sold either on a FOB basis (delivered to the customer at the Sabine Pass LNG terminal or the Corpus Christi LNG terminal, as applicable) or a delivered at terminal (“DAT”) basis (delivered to the customer at their specified LNG receiving terminal). We have chartered LNG vessels to be utilized for cargoes sold on a DAT basis.

Cheniere Marketing has uncommitted trade finance facilities with available credit of $240 million as of June 30, 2021, primarily to be used for the purchase and sale of LNG for ultimate resale in the course of its operations. The finance facilities are intended to be used for advances, guarantees or the issuance of letters of credit or standby letters of credit on behalf of Cheniere Marketing. As of June 30, 2021 and December 31, 2020, Cheniere Marketing had $5 million and $34 million, respectively, in standby letters of credit and guarantees outstanding under the finance facilities. As of June 30, 2021 and December 31, 2020, there were $30 million and zero loans outstanding, respectively, under the finance facilities. Cheniere Marketing pays interest or fees on utilized commitments.

Cheniere Marketing also has an uncommitted letter of credit facility with no available credit as of June 30, 2021, for the issuance of letters of credit in the course of its operations. As of June 30, 2021, Cheniere Marketing had $35 million of letters of credit issued under the facility. Cheniere Marketing pays fees on utilized commitments.

~~Corporate and Other Activities~~

We are required to maintain corporate and general and administrative functions to serve our business activities described above. The development of our sites 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 an FID.

We have made an equity investment in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“the Midship Pipeline”). Midship Pipeline operates the Midship Project with current capacity of up to 1.1 million Dekatherms per day that connects new gas production in the Anadarko Basin to Gulf Coast markets, including markets serving the Liquefaction Projects. The Midship Project was placed in service in April 2020.

~~Restrictive Debt Covenants~~

~~As of June 30, 2021, each of our issuers was in compliance with all covenants related to their respective debt agreements.~~

~~LIBOR~~

The use of LIBOR is expected to be phased out by June 2023. It is currently unclear whether LIBOR will be utilized beyond that date or whether it will be replaced by a particular rate. We intend to continue working with our lenders and counterparties to pursue any amendments to our debt and derivative agreements that are currently subject to LIBOR following LIBOR cessation and will continue to monitor, assess and plan for the phase out of LIBOR.

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash, cash equivalents and restricted cash ~~for the six months ended June 30, 2021~~ and ~~2020~~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,
2021 2020
Sources of cash, cash equivalents and restricted cash:
Net cash provided by operating activities $ 1,373 $ 1,028
Proceeds from sale of fixed assets 68 —
Proceeds from issuances of debt 2,184 2,597
Other 8 —
$ 3,633 $ 3,625
Uses of cash, cash equivalents and restricted cash:
Property, plant and equipment $ (440) $ (983)
Investment in equity method investment — (100)
Repayments of debt (2,603) (2,380)
Debt issuance and other financing costs (20) (59)
Debt modification or extinguishment costs (41) (40)
Distributions to non-controlling interest (322) (310)
Payments related to tax withholdings for share-based compensation (43) (41)
Repurchase of common stock — (155)
Other (11) (7)
(3,480) (4,075)
Net increase (decrease) in cash, cash equivalents and restricted cash $ 153 $ (450)


	Three Months Ended March 31,
	2022		2021

Net cash provided by operating activities	$	2,655	$	1,066
Net cash used in investing activities	(178)		(200)
Net cash used in financing activities	(1,388)		(545)

















Net increase in cash, cash equivalents and restricted cash and cash equivalents	$	1,089	$	321

Operating Cash Flows

Our operating cash net inflows during the ~~six~~three months ended ~~June 30,~~March 31, 2022 and 2021 ~~and 2020~~ were ~~$1,373~~$2,655 million and ~~$1,028~~$1,066 million, respectively. The ~~$345~~$1,589 million increase in operating cash inflows in ~~2021~~2022 compared to ~~2020~~2021 was primarily related to increased cash receipts from the sale of LNG cargoes due to higher revenue per MMBtu and to a lesser extent higher volume of LNG delivered, as well as from higher than normal contributions from LNG and natural gas portfolio optimization activities due to significant volatility in LNG and natural gas markets during the six months ended June 30, 2021.delivered. Partially offsetting these operating cash inflows were higher operating cash outflows primarily due to higher natural gas feedstock costs and ~~payment of paid-in-kind interest on our convertible notes.~~lower contribution from certain portfolio optimization activities.

~~Proceeds from Sale of Fixed Assets~~Investing Cash Flows

~~During the six months ended June 30, 2021, we received proceeds from the sale of fixed assets of $68 million from divestment of non-core land holdings.~~

~~Proceeds from Issuance of Debt, Repayments of Debt, Debt Issuance and Other Financing Costs and Debt Modification or Extinguishment Costs~~

During the six months ended June 30, 2021, Cheniere Partners issued an aggregate principal amount of $1.5 billion of the 2031 CQP Senior Notes and incurred $20 million of debt issuance costs related to this issuance. The proceeds from this issuance, together withOur investing cash on hand, were used to redeem all of the outstanding 2025 CQP Senior Notes, and Cheniere Partners paid $40 million of debt extinguishment costs, mainly related to premiums associated with this redemption. Additionally,net outflows in line with our previously announced capital allocation priorities, we repaid $624 million of total outstanding indebtedness under the Cheniere Term Loan Facility and 2021 Cheniere Convertible Notes with $500 million of available cash and the remainder from borrowings under the Cheniere Revolving Credit Facility. We paid $2 million of debt extinguishment costs as a result of the repayment of the 2021 Cheniere Convertible Notes. Additionally, net repayments of $100 million were made on our credit facilities during the six months ended June 30, 2021.

~~During the six months ended June 30, 2020, SPL issued an aggregate principal amount of $2.0 billion of the 2030 SPL Senior Notes, which along with cash on hand~~both years primarily was used to redeem all of the outstanding 2021 SPL Senior Notes. During the six months ended June 30, 2020, borrowings of $0.6 billion under our credit facilities were used to redeem the 11% Convertible Senior Secured Notes due 2025 (the “2025 CCH HoldCo II Convertible Senior Notes”), to fund our working capital requirements or for general corporate purposes. We incurred $59 million of debt issuance costs primarily related to up-front fees paid upon the closing of the 2020 SPL Working Capital Facility and 2030 SPL Senior Notes and premiums paid for partially redeeming the 2025 CCH HoldCo II Convertible Senior Notes. We incurred $40 million of debt extinguishment costs primarily related to the redemption of the 2021 SPL Senior Notes.

~~Property, Plant and Equipment~~

~~Cash outflows for property, plant and equipment were primarily~~ for the construction costs for the Liquefaction Projects. The $22 million decrease in 2022 compared to 2021 was primarily due to the completion of Train 6 of the SPL Project in February 2022, which was under construction throughout 2021. These costs are capitalized as construction-in-process until achievement of substantial completion.

~~Distributions to Non-controlling Interest~~Financing Cash Flows

WeDuring the three months ended March 31, 2022, total debt paid, net of issuances, was $1,040 million. During the three months ended March 31, 2021, total debt paid, net of issuances, was $288 million. See tables below for additional details.

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Debt Issuances and Related Financing Costs

The following table shows the issuances of debt, including intra-quarter borrowings (in millions):


	Three Months Ended March 31,
	2022		2021





CQP:

4.000% Senior Notes due 2031	$	—	$	1,500









Cheniere:

Cheniere Revolving Credit Facility	575		300

Total issuances	$	575	$	1,800

During the three months ended March 31, 2022 and 2021, we incurred debt issuance costs and other financing costs of zeroand$19 million, respectively, related to the debt issuances above and closing of credit facilities during the respective periods.

Debt Redemptions and Repayments and Related Modification or Extinguishment Costs

The following table shows the redemptions and repayments of debt, including intra-quarter repayments (in millions):


	Three Months Ended March 31,
	2022		2021





CQP:
5.250% Senior Notes due 2025	$	—	$	(1,500)



CCH:
CCH Working Capital Facility	(250)		(140)
CCH amended and restated term loan facility	(290)		—

Cheniere:
2045 Cheniere Convertible Senior Notes	(500)		—
Cheniere Revolving Credit Facility	(575)		(300)
Cheniere’s term loan facility	—		(148)

Total redemption and repayments	$	(1,615)	$	(2,088)

During the three months ended March 31, 2022 and 2021, we paid debt modification or extinguishment costs of $13 million and$40 million, respectively, related to these redemptions and repayments.

Non-Controlling Interest Distributions

CQP paid distributions of $171 million and $160 million during the three months ended March 31, 2022 and 2021, respectively, to non-controlling interests since we own a 48.6% limited partner interest in ~~Cheniere Partners, with~~CQP and the remaining non-controlling interest is held by ~~The~~ Blackstone ~~Group~~ Inc., Brookfield Asset Management Inc. and the ~~public, to whom Cheniere Partners paid distributions during the three and six months ended June 30, 2021 and 2020.~~public.

Repurchase of Common Stock

During the ~~six~~three months ended ~~June 30, 2020,~~March 31, 2022, we paid ~~$155~~$25 million to repurchase approximately ~~2.9~~0.24 million shares of our common stock under ~~the~~our share repurchase program. ~~There were no~~We did not have any share repurchases ~~paid in cash~~ during the ~~six~~three months ended ~~June 30,~~March 31, 2021.

Cash Dividends to Shareholders

~~Off-Balance Sheet Arrangements~~

On January 25, 2022, we declared a quarterly dividend of $0.33 per share of common stock that was paid on February 28, 2022 to shareholders of record as of February 7, 2022, for a total payment of $86 million. We did not pay dividends during the three months ended March 31, 2021.

Table of ~~June 30, 2021,~~Contents

On April 26, 2022, we ~~had no transactions~~declared a quarterly dividend of $0.33 per share of common stock that ~~met the definition~~is payable on May 17, 2022 to shareholders of ~~off-balance sheet arrangements that may have a current or future material effect on our consolidated financial position or operating results.~~record as of May 10, 2022.

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, ~~2020~~2021..

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 entered into commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the SPL Project, the CCL Project and potential future development of Corpus Christi Stage 3 (“Liquefaction Supply Derivatives”). We have also entered into physical and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives and the LNG Trading Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location and a 10% change in the commodity price for LNG, respectively, as follows (in millions):


		June 30, 2021				December 31, 2020					March 31, 2022				December 31, 2021
		Fair Value		Change in Fair Value		Fair Value		Change in Fair Value			Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Liquefaction Supply Derivatives	Liquefaction Supply Derivatives	$	(197)	$	246	$	240	$	204	Liquefaction Supply Derivatives	$	(7,489)	$	1,749	$	(4,038)	$	903
LNG Trading Derivatives	LNG Trading Derivatives	(401)		49		(134)		44		LNG Trading Derivatives	(268)		26		(400)		38

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

Interest Rate Risk

We are exposed to interest rate risk primarily when we incur debt related to project financing. Interest rate risk is managed in part by replacing outstanding floating-rate debt with fixed-rate debt with varying maturities. CCH has entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the CCH Credit Facility (“~~CCH~~ Interest Rate Derivatives”). In order to test the sensitivity of the fair value of the ~~CCH~~ Interest Rate Derivatives to changes in interest rates, management modeled a 10% change in the forward one-month LIBOR curve across the remaining terms of the ~~CCH~~ Interest Rate Derivatives as follows (in millions):

June 30, 2021 December 31, 2020
Fair Value Change in Fair Value Fair Value Change in Fair Value
CCH Interest Rate Derivatives $ (91) $ 1 $ (140) $ 1


	March 31, 2022				December 31, 2021
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Interest Rate Derivatives	$	(12)	$	1	$	(40)	$	—

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

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Foreign Currency Exchange Risk

We have entered into foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with operations in countries outside of the United States (“FX Derivatives”). In order to test the sensitivity of the fair value of the FX Derivatives to changes in FX rates, management modeled a 10% change in FX rate between the U.S. dollar and the applicable foreign currencies as follows (in millions):

June 30, 2021 December 31, 2020
Fair Value Change in Fair Value Fair Value Change in Fair Value
FX Derivatives $ (4) $ — $ (22) $ 2


	March 31, 2022				December 31, 2021
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
FX Derivatives	$	25	$	2	$	12	$	2

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 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 management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our 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. Other than discussed below, 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, ~~2020~~2021.

~~In February 2018,~~Louisiana Department of Environmental Quality (“LDEQ”) Matter

Certain of our subsidiaries are in discussions with the LDEQ to resolve self-reported deviations arising from operation of the Sabine Pass LNG Terminal and the commissioning of the SPL Project, and relating to certain requirements under its Title V Permit.The matter involves deviations self-reported to LDEQ pursuant to the Title V Permit and covering the time period from January 1, 2012 through March 25, 2016.On April 11, 2016, certain of our subsidiaries received a Consolidated Compliance Order and Notice of Potential Penalty (the “Compliance Order”) from LDEQ covering deviations self-reported during that time period.Certain of our subsidiaries continue to work with LDEQ to resolve the matters identified in the Compliance Order.We do not expect that any ultimate sanction will have a material adverse impact on our financial results.

Pipeline and Hazardous Materials Safety Administration (“PHMSA”) Matter

In February 2018, the PHMSA issued a Corrective Action Order (the “CAO”) to SPL in connection with a minor LNG leak from one tank and minor vapor release from a second tank at the Sabine Pass LNG ~~terminal.~~ Terminal (the “2018 SPL tank incident”).These two tanks have been taken out of operational service while we conduct analysis, repair and remediation.On April 20, 2018, SPL and PHMSA executed a Consent Agreement and Order (the “Consent Order”) that replaces and supersedes the CAO.On July 9, 2019, PHMSA and FERC issued a joint letter setting out operating conditions required to be met prior to SPL returning the tanks to service.In July 2021, PHMSA issued a Notice of Probable Violation (“NOPV”) and Proposed Civil Penalty to SPL alleging violations of federal pipeline safety regulations relating to the 2018 SPL tank incident and proposing civil penalties totaling $2,214,900. ~~We continue~~On September 16, 2021, PHMSA issued an Amended NOPV that reduced the proposed penalty to $1,458,200.On October 12, 2021, SPL responded to the Amended NOPV, electing not to contest the alleged violations in the Amended NOPV and electing to pay the proposed reduced penalty.PHMSA notified SPL in a letter dated November 9, 2021 that the case was considered “closed.”On March 9, 2022, PHMSA and FERC issued conditional approval to return one of the two tanks to service. SPL continues to coordinate with PHMSA and FERC to address the matters relating to the ~~February~~ 2018 ~~leak,~~SPL tank incident, including repair approach and related analysis.We do not expect that the Consent Order and related analysis, repair and remediation or resolution of the NOPV will have a material adverse impact on our financial results or operations.

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, ~~2020~~2021.

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ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchase of Equity Securities by the Issuer and Affiliated Purchasers

The following table summarizes stock repurchases for the three months ended ~~June 30, 2021:~~March 31, 2022:

Period Total Number of Shares Purchased (1) Average Price Paid Per Share (2) Total Number of Shares Purchased as a Part of Publicly Announced Plans Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (3)
April 1 - 30, 2021 4,734 $72.83 — $595,952,809
May 1 - 31, 2021 2,624 $77.52 — $595,952,809
June 1 - 30, 2021 — $— — $595,952,809
Total 7,358 $74.50 —


Period	Total Number of Shares Purchased (1)	Average Price Paid Per Share (2)	Total Number of Shares Purchased as a Part of Publicly Announced Plans	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (3)
January 1 - 31, 2022	239,320	$104.20	238,537	$972,714,359
February 1 - 28, 2022	298,073	$119.38	—	$972,714,359
March 1 - 31, 2022	—	$—	—	$972,714,359
Total	537,393	$112.62	238,537

(1)Includes issued shares surrendered to us by participants in our share-based compensation plans for payment of applicable tax withholdings on the vesting of share-based compensation awards. Associated shares surrendered by participants are repurchased pursuant to terms of the plan and award agreements and not as part of the publicly announced share repurchase plan.

(2)The price paid per share was based on the average trading price of our common stock on the dates on which we repurchased the shares.

(3)On ~~June 3, 2019, we~~September 7, 2021, the Board of Directors authorized an increase in the previously announced ~~that our Board authorized a 3-year, $1 billion~~ share repurchase ~~program.~~program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. For additional information, see ~~Share Repurchase Program~~ in ~~Liquidity and Capital Resources~~Note 15—Stockholders' Deficit.

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ITEM 6. EXHIBITS

Exhibit No.

Description

10.1*†

~~Form~~Fixed Price Separated Turnkey Agreement for the Engineering, Procurement and Construction of ~~Restricted Stock Grant under~~ the ~~Cheniere 2020 Incentive Plan (Director)~~Corpus Christi Liquefaction Sta ge 3 Project, dated March 1, 2022, by and between Corpus Ch risti L iquefaction Sta ge III, LLC and Bechtel Energy Inc. (Portions of this exhibit have been omitted )

10.2*

Fourth Amendment to Common Security and Account Agreement, dated as of April 1, 2021, among CCH, CCL, CCP and Corpus Christi Pipeline GP, LLC, the Senior Creditor Group Representatives, Société Générale as Intercreditor Agent for the Facility Lenders and any Hedging Banks, Société Générale as Security Trustee, and Mizuho Bank, Ltd. as Account Bank.

10.3*

Sixth Amendment to the Amended and Restated Common Terms Agreement, dated as of April 1, 2021, by and among CCH, CCL, CCP and Corpus Christi Pipeline GP, LLC, Société Générale as the Term Loan Facility Agent, The Bank of Nova Scotia as the Working Capital Facility Agent, each other Facility Agent on behalf of its respective Facility Lenders, and Société Générale as the Intercreditor Agent

10.4*10.2*

Change orders to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 4 Liquefaction Facility, dated November 7, 2018, by and between SPL and Bechtel Oil Gas and Chemicals, Inc.: (i) the Change Order ~~CO-000~~CO-00058 COVID-19 Impacts 3Q2021, dated January 6, 2022, 43 ~~Third Berth SVT Loading Arm Spares~~,(ii) CO-00059 Spill Containment SIL 2 Interlock, dated ~~April 9, 202~~1 ~~, (ii) the Change Order CO-000~~44 ~~Third Berth~~ ~~U/G Directional Drilling & Cathodic Protection Provisional Sum Closures, dated~~ ~~April 9, 202~~1 ,January 11, 2022, (iii) the Change Order ~~CO-000~~45 ~~Winter~~ ~~Storm Impacts~~,CO-00060 Third Berth Soil Preparation Provisional Sum Closure, dated Ap ~~ril 9, 2021, (i~~v )March 15, 2022, (iv) the Change Order ~~CO-00046 NGPL Security Provisional Sum Interim Adjustment,~~CO-00061 COVID-19 Impacts 4Q2021, dated J ~~une~~March 15, ~~2021,~~2022 and (v) the Change Order ~~CO-00047 80~~ ~~Acres~~ ~~Bridge,~~CO-00062 FERC Condition 61, dated ~~June~~March 15, ~~2021 and (vi) the Change Order CO-0004~~8 A ~~GRU Additions for Lean Solvent Overpressure, dated June 15, 20~~2 12022

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.
†			~~Management contract or compensatory plan or arrangement.~~

5341

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, INC.







Date:	~~August 4, 2021~~May 3, 2022	By:	/s/ Zach Davis
			Zach Davis
			~~Senior~~Executive Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)

Date:	~~August 4, 2021~~May 3, 2022	By:	/s/ ~~Leonard E. Travis~~David Slack
			~~Leonard E. Travis~~David Slack
			~~Senior~~ Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

5442


	Three Months Ended June 30, 2021		Six Months Ended June 30, 2021
(in TBtu)	Operational	Commissioning	Operational	Commissioning
Volumes loaded during the current period	499	—	947	28
Volumes loaded during the prior period but recognized during the current period	32	6	26	3
Less: volumes loaded during the current period and in transit at the end of the period	(23)	—	(23)	—
Total volumes recognized in the current period	508	6	950	31