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 JuneSeptember 30, 2020
or
☐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 333-215435
Cheniere Corpus Christi Holdings, LLC 
(Exact name of registrant as specified in its charter)
Delaware47-1929160
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification No.)
700 Milam Street,, Suite 1900
Houston,, Texas77002
(Address of principal executive offices) (Zip Code)
(713) (713) 375-5000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading SymbolName of each exchange on which registered
NoneNoneNone
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 ☒
Note: The registrant iswas a voluntary filer not subject to the filing requirements of Sections 13 or 15(d) of the Securities Exchange Act of 1934. However, theuntil September 24, 2020. The registrant has filed all reports required pursuant to Sections 13 or 15(d) during the preceding 12 months as if the registrant was subject to such filing requirements.
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 ☒
Indicate the number of shares outstanding of the issuer’s classes of common stock, as of the latest practicable date:    Not applicable


CHENIERE CORPUS CHRISTI HOLDINGS, LLC
TABLE OF CONTENTS




1
Part I. Financial Information
3
Consolidated Balance Sheets
3
Consolidated Statements of Operations
4
Consolidated Statements of Member’s Equity
5
Consolidated Statements of Cash Flows
6
Notes to Consolidated Financial Statements
7
2122
3235
3335
Part II. Other Information
3436
3436
3436
3537

i


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

Common Industry and Other Terms
Bcfbillion cubic feet
Bcf/dbillion cubic feet per day
Bcf/yrbillion cubic feet per year
Bcfebillion cubic feet equivalent
DOEU.S. Department of Energy
EPCengineering, procurement and construction
FERCFederal Energy Regulatory Commission
FTA countriescountries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAPgenerally accepted accounting principles in the United States
Henry Hubthe 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
LIBORLondon Interbank Offered Rate
LNGliquefied 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
MMBtumillion British thermal units, an energy unit
mtpamillion tonnes per annum
non-FTA countriescountries 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
SECU.S. Securities and Exchange Commission
SPALNG sale and purchase agreement
TBtutrillion British thermal units, an energy unit
Trainan industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG

1

Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of JuneSeptember 30, 2020, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:
cch-20200930_g1.jpg
Unless the context requires otherwise, references to “CCH,” the “Company,” “we,” “us,” and “our” refer to Cheniere Corpus Christi Holdings, LLC and its consolidated subsidiaries.
2

PART I.FINANCIAL INFORMATION
PART I.    FINANCIAL INFORMATION
ITEM 1.CONSOLIDATED FINANCIAL STATEMENTS
ITEM 1.    CONSOLIDATED FINANCIAL STATEMENTS
CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(in millions)





September 30,December 31,
20202019
ASSETS(unaudited)
Current assets
Cash and cash equivalents$0 $0 
Restricted cash145 80 
Accounts and other receivables, net117 58 
Accounts receivable—affiliate36 57 
Advances to affiliate103 115 
Inventory82 69 
Derivative assets81 74 
Derivative assets—related party1 3 
Other current assets27 15 
Total current assets592 471 
Property, plant and equipment, net12,713 12,507 
Debt issuance and deferred financing costs, net12 15 
Non-current derivative assets195 61 
Non-current derivative assets—related party0 2 
Other non-current assets, net77 56 
Total assets$13,589 $13,112 
LIABILITIES AND MEMBER’S EQUITY 
Current liabilities 
Accounts payable$9 $7 
Accrued liabilities315 370 
Accrued liabilities—related party13 3 
Current debt248 0 
Due to affiliates30 27 
Derivative liabilities121 46 
Other current liabilities1 0 
Other current liabilities—affiliate0 1 
Total current liabilities737 454 
Long-term debt, net10,117 10,093 
Non-current derivative liabilities147 135 
Other non-current liabilities10 11 
Other non-current liabilities—affiliate0 1 
Member’s equity2,578 2,418 
Total liabilities and member’s equity$13,589 $13,112 

  June 30, December 31,
  2020 2019
ASSETS (unaudited)  
Current assets    
Cash and cash equivalents $—
 $—
Restricted cash 101
 80
Accounts and other receivables 283
 58
Accounts receivable—affiliate —
 57
Advances to affiliate 106
 115
Inventory 75
 69
Derivative assets 108
 74
Derivative assets—related party 5
 3
Other current assets 24
 15
Total current assets 702
 471
     
Property, plant and equipment, net 12,546
 12,507
Debt issuance and deferred financing costs, net 13
 15
Non-current derivative assets 159
 61
Non-current derivative assets—related party 2
 2
Other non-current assets, net 73
 56
Total assets $13,495
 $13,112
     
LIABILITIES AND MEMBER’S EQUITY    
Current liabilities    
Accounts payable $8
 $7
Accrued liabilities 148
 370
Accrued liabilities—related party 9
 3
Current debt 141
 —
Due to affiliates 20
 27
Derivative liabilities 223
 46
Other current liabilities 2
 —
Other current liabilities—affiliate 1
 1
Total current liabilities 552
 454
     
Long-term debt, net 10,106
 10,093
Non-current derivative liabilities 160
 135
Other non-current liabilities 9
 11
Other non-current liabilities—affiliate —
 1
     
Member’s equity 2,668
 2,418
Total liabilities and member’s equity $13,495
 $13,112


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

3

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(in millions)
(unaudited)


Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
Revenues
LNG revenues$337 $220 $1,290 $351 
LNG revenues—affiliate106 167 340 442 
Total revenues443 387 1,630 793 
Operating costs and expenses
Cost of sales (excluding items shown separately below)180 302 369 541 
Cost of sales—affiliate16 2 24 2 
Cost of sales—related party29 23 77 59 
Operating and maintenance expense91 63 275 156 
Operating and maintenance expense—affiliate23 15 68 36 
Operating and maintenance expense—related party2 0 4 0 
Development expense0 0 0 1 
General and administrative expense1 2 5 5 
General and administrative expense—affiliate5 4 15 7 
Depreciation and amortization expense86 67 256 146 
Impairment expense and loss on disposal of assets1 0 1 0 
Total operating costs and expenses434 478 1,094 953 
Income (loss) from operations9 (91)536 (160)
Other income (expense)
Interest expense, net of capitalized interest(89)(90)(278)(175)
Loss on modification or extinguishment of debt(9)(14)(9)(14)
Interest rate derivative loss, net0 (78)(233)(187)
Other income, net1 0 1 3 
Total other expense(97)(182)(519)(373)
Net income (loss)$(88)$(273)$17 $(533)

 Three Months Ended June 30, Six Months Ended June 30,
 2020 2019 2020 2019
Revenues       
LNG revenues$610
 $118
 $953
 $131
LNG revenues—affiliate44
 182
 234
 275
Total revenues654
 300
 1,187
 406
        
Operating costs and expenses       
Cost of sales (excluding items shown separately below)140
 180
 189
 239
Cost of sales—affiliate2
 —
 8
 —
Cost of sales—related party25
 26
 48
 36
Operating and maintenance expense95
 61
 184
 93
Operating and maintenance expense—affiliate25
 16
 45
 21
Operating and maintenance expense—related party2
 —
 2
 —
Development expense—
 1
 —
 1
General and administrative expense2
 1
 4
 3
General and administrative expense—affiliate5
 2
 10
 3
Depreciation and amortization expense86
 57
 170
 79
Total operating costs and expenses382
 344
 660
 475
        
Income (loss) from operations272
 (44) 527
 (69)
        
Other income (expense)       
Interest expense, net of capitalized interest(90) (73) (189) (85)
Interest rate derivative loss, net(25) (74) (233) (109)
Other income (expense), net(1) 2
 —
 3
Total other expense(116) (145) (422) (191)
        
Net income (loss)$156
 $(189) $105
 $(260)




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

4

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF MEMBER’S EQUITY
(in millions)
(unaudited)




Three and Nine Months Ended September 30, 2020
Cheniere CCH HoldCo I, LLC
Total Member’s
Equity
Balance at December 31, 2019$2,418 $2,418 
Net loss(51)(51)
Balance at March 31, 20202,367 2,367 
Capital contributions145 145 
Net income156 156 
Balance at June 30, 20202,668 2,668 
Distributions(2)(2)
Net loss(88)(88)
Balance at September 30, 2020$2,578 $2,578 

Three and Six Months Ended June 30, 2020   
 Cheniere CCH HoldCo I, LLC 
Total Member’s
Equity
Balance at December 31, 2019$2,418
 $2,418
Net loss(51) (51)
Balance at March 31, 20202,367
 2,367
Capital contributions145
 145
Net income156
 156
Balance at June 30, 2020$2,668
 $2,668
Three and Nine Months Ended September 30, 2019
Cheniere CCH HoldCo I, LLC
Total Member’s
Equity
Balance at December 31, 2018$2,081 $2,081 
Net loss(71)(71)
Balance at March 31, 20192,010 2,010 
Capital contributions72 72 
Net loss(189)(189)
Balance at June 30, 20191,893 1,893 
Capital contributions331 331 
Net loss(273)(273)
Balance at September 30, 2019$1,951 $1,951 

Three and Six Months Ended June 30, 2019   
 Cheniere CCH HoldCo I, LLC 
Total Member’s
Equity
Balance at December 31, 2018$2,081
 $2,081
Net loss(71) (71)
Balance at March 31, 20192,010
 2,010
Capital contributions72
 72
Net loss(189) (189)
Balance at June 30, 2019$1,893
 $1,893


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

5

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in millions)
(unaudited)


Nine Months Ended September 30,
20202019
Cash flows from operating activities 
Net income (loss)$17 $(533)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and amortization expense256 146 
Amortization of discount and debt issuance costs16 10 
Loss on modification or extinguishment of debt9 14 
Total losses on derivatives, net93 289 
Total losses on derivatives, net—related party3 4 
Net cash provided by (used for) settlement of derivative instruments(146)4 
Impairment expense and loss on disposal of assets1 0 
Other(1)1 
Changes in operating assets and liabilities:
Accounts receivable(59)(44)
Accounts receivable—affiliate21 (49)
Advances to affiliate16 (37)
Inventory(13)(38)
Accounts payable and accrued liabilities78 186 
Accrued liabilities—related party11 2 
Due to affiliates7 9 
Other, net(47)(5)
Other, net—affiliate(1)0 
Net cash provided by (used in) operating activities261 (41)
Cash flows from investing activities 
Property, plant and equipment, net(583)(1,255)
Other(4)(2)
Net cash used in investing activities(587)(1,257)
Cash flows from financing activities 
Proceeds from issuances of debt910 2,189 
Repayments of debt(656)(1,446)
Debt issuance and deferred financing costs(8)(5)
Capital contributions145 403 
Net cash provided by financing activities391 1,141 
Net increase (decrease) in cash, cash equivalents and restricted cash65 (157)
Cash, cash equivalents and restricted cash—beginning of period80 289 
Cash, cash equivalents and restricted cash—end of period$145 $132 
 Six Months Ended June 30,
 2020 2019
Cash flows from operating activities   
Net income (loss)$105
 $(260)
Adjustments to reconcile net loss to net cash used in operating activities:   
Depreciation and amortization expense170
 79
Amortization of discount and debt issuance costs10
 5
Total losses on derivatives, net90
 98
Total losses (gains) on derivatives, net—related party(2) 3
Net cash provided by (used for) settlement of derivative instruments(20) 4
Other—
 1
Changes in operating assets and liabilities:   
Accounts receivable(225) (39)
Accounts receivable—affiliate57
 (22)
Advances to affiliate10
 (31)
Inventory(6) (31)
Accounts payable and accrued liabilities(67) 134
Accrued liabilities—related party6
 4
Due to affiliates(2) 6
Other, net(39) (4)
Net cash provided by (used in) operating activities87
 (53)
    
Cash flows from investing activities 
  
Property, plant and equipment, net(350) (840)
Other(2) (2)
Net cash used in investing activities(352) (842)
    
Cash flows from financing activities 
  
Proceeds from issuances of debt141
 1,372
Repayments of debt—
 (558)
Debt issuance and deferred financing costs—
 (1)
Capital contributions145
 72
Net cash provided by financing activities286
 885
    
Net increase (decrease) in cash, cash equivalents and restricted cash21
 (10)
Cash, cash equivalents and restricted cash—beginning of period80
 289
Cash, cash equivalents and restricted cash—end of period$101
 $279

Balances per Consolidated Balance Sheet:
September 30,
2020
Cash and cash equivalents$0 
Restricted cash145 
Total cash, cash equivalents and restricted cash$145 
 June 30,
 2020
Cash and cash equivalents$—
Restricted cash101
Total cash, cash equivalents and restricted cash$101





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

6

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)




NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We are operating and constructing a natural gas liquefaction and export facility (the “Liquefaction Facilities”) and operating a 23-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 Liquefaction Facilities, the “Liquefaction Project”) near Corpus Christi, Texas, through our subsidiaries CCL and CCP, respectively. We are currently operating 2 Trains and 1 additional Train is undergoing commissioning for a total production capacity of approximately 15 mtpa of LNG. The Liquefaction Project, once fully constructed, will contain 3 LNG storage tanks and 2 marine berths.

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of CCH have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2019. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications did not have a material effect on our consolidated financial position, results of operations or cash flows.

Results of operations for the three and sixnine months ended JuneSeptember 30, 2020 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2020.

We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is included in the consolidated federal income tax return of Cheniere. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Consolidated Financial Statements.

Recent Accounting Standards

In March 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we 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.

NOTE 2—RESTRICTED CASH

Restricted cash consists 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 JuneSeptember 30, 2020 and December 31, 2019, we had $101$145 million and $80 million of current restricted cash, respectively.

Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments.

7

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 3—ACCOUNTS AND OTHER RECEIVABLES

As of JuneSeptember 30, 2020 and December 31, 2019, accounts and other receivables, net consisted of the following (in millions):
September 30,December 31,
20202019
Trade receivable$74 $44 
Other accounts receivable43 14 
Total accounts and other receivables$117 $58 
  June 30, December 31,
  2020 2019
Trade receivable $222
 $44
Other accounts receivable 61
 14
Total accounts and other receivables $283
 $58


NOTE 4—INVENTORY

As of JuneSeptember 30, 2020 and December 31, 2019, inventory consisted of the following (in millions):
September 30,December 31,
20202019
Natural gas$7 $7 
LNG11 6 
Materials and other64 56 
Total inventory$82 $69 
  June 30, December 31,
  2020 2019
Natural gas $6
 $7
LNG 8
 6
Materials and other 61
 56
Total inventory $75
 $69


NOTE 5—PROPERTY, PLANT AND EQUIPMENT
 
As of JuneSeptember 30, 2020 and December 31, 2019, property, plant and equipment, net consisted of the following (in millions):
September 30,December 31,
20202019
LNG terminal costs
LNG terminal and interconnecting pipeline facilities$10,172 $10,027 
LNG site and related costs276 276 
LNG terminal construction-in-process2,739 2,425 
Accumulated depreciation(483)(232)
Total LNG terminal costs, net12,704 12,496 
Fixed assets
Fixed assets21 19 
Accumulated depreciation(12)(8)
Total fixed assets, net9 11 
Property, plant and equipment, net$12,713 $12,507 
  June 30, December 31,
  2020 2019
LNG terminal costs    
LNG terminal and interconnecting pipeline facilities $10,164
 $10,027
LNG site and related costs 276
 276
LNG terminal construction-in-process 2,495
 2,425
Accumulated depreciation (399) (232)
Total LNG terminal costs, net 12,536
 12,496
Fixed assets    
Fixed assets 21
 19
Accumulated depreciation (11) (8)
Total fixed assets, net 10
 11
Property, plant and equipment, net $12,546
 $12,507


DepreciationThe following table shows depreciation expense was $86 million and $57 million during the three months ended June 30, 2020 and 2019, respectively, and $170 million and $79 million during the six months ended June 30, 2020 and 2019, respectively.

We realized offsets to LNG terminal costs of $8 million and $82 million during the three and sixnine months ended JuneSeptember 30, 2020 and 2019 respectively, that were(in millions):
Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
Depreciation expense$85 $67 $255 $146 
Offsets to LNG terminal costs (1)0 74 0 156 
(1)    We realize 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 Liquefaction Project during the testing phase for its construction. We did 0t realize any offsets to LNG terminal costs during the three and six months ended June 30, 2020.



8

CHENIERE CORPUS CHRISTI HOLDINGS, LLC 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 our amended and restated credit facility (the “CCH Credit Facility”) and to hedge against changes in interest rates that could impact anticipated future issuance of debt (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”) and

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

•commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (collectively, the “Liquefaction Supply Derivatives”).

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow 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.

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 JuneSeptember 30, 2020 and December 31, 2019, which are classified as derivative assets, derivative assets—related party, non-current derivative assets, non-current derivative assets—related party, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in millions):
Fair Value Measurements as of
September 30, 2020December 31, 2019
Quoted Prices in Active Markets
(Level 1)		Significant Other Observable Inputs
(Level 2)		Significant Unobservable Inputs
(Level 3)		TotalQuoted Prices in Active Markets
(Level 1)		Significant Other Observable Inputs
(Level 2)		Significant Unobservable Inputs
(Level 3)		Total
CCH Interest Rate Derivatives liability$0 $(165)$0 $(165)$0 $(81)$0 $(81)
CCH Interest Rate Forward Start Derivatives liability0 0 0 0 0 (8)0 (8)
Liquefaction Supply Derivatives asset0 0 174 174 3 10 35 48 
 Fair Value Measurements as of
 June 30, 2020 December 31, 2019
 
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$—
 $(191) $—
 $(191) $—
 $(81) $—
 $(81)
CCH Interest Rate Forward Start Derivatives liability—
 (102) —
 (102) —
 (8) —
 (8)
Liquefaction Supply Derivatives asset9
 2
 173
 184
 3
 10
 35
 48


We value our Interest Rate Derivatives using an income-based approach utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our Liquefaction Supply Derivatives using a market-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data.

The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by 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 whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of JuneSeptember 30, 2020 and December 31, 2019, some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow.

We include a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which 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.
9

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The Level 3 fair value measurements of natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of JuneSeptember 30, 2020:
Net Fair Value Asset

(in millions)
Valuation ApproachSignificant Unobservable InputRange of Significant Unobservable Inputs / Weighted Average (1)
Physical Liquefaction Supply Derivatives$173174Market approach incorporating present value techniquesHenry Hub basis spread$(0.546)(0.557) - $0.172$0.050 / $(0.057)$(0.068)
Option pricing modelInternational LNG pricing spread, relative to Henry Hub (2)46%56% - 158%165% / 105%118%

(1)    Unobservable inputs were weighted by the relative fair value of the instruments.
(2)     Spread contemplates U.S. dollar-denominated pricing.    

Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Physical Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives, including those with related parties, during the three and sixnine months ended JuneSeptember 30, 2020 and 2019 (in millions):
Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
Balance, beginning of period$173 $6 $35 $(4)
Realized and mark-to-market gains (losses):
Included in cost of sales28 (124)196 (117)
Purchases and settlements:
Purchases(4)17 (2)18 
Settlements(23)(1)(55)1 
Balance, end of period$174 $(102)$174 $(102)
Change in unrealized gains (losses) relating to instruments still held at end of period$28 $(124)$196 $(117)
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
Balance, beginning of period $202
 $2
 $35
 $(4)
Realized and mark-to-market gains:        
Included in cost of sales (31) 4
 134
 7
Purchases and settlements:        
Purchases (3) —
 (3) 1
Settlements 2
 (1) 5
 2
Transfers into Level 3, net (1) 3
 1
 2
 —
Balance, end of period $173
 $6
 $173
 $6
Change in unrealized gains (losses) relating to instruments still held at end of period $(31) $4
 $134
 $7

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

Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for the unconditional right of set-off in the event of default. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

10

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

Interest Rate Derivatives

In August 2020, we settled the outstanding CCH Interest Rate Forward Start Derivatives used to hedge against changes in the interest rates of our debt.

As of JuneSeptember 30, 2020, we had the following Interest Rate Derivatives outstanding:
Notional Amounts
September 30, 2020December 31, 2019Maturity DateWeighted Average Fixed Interest Rate PaidVariable Interest Rate Received
CCH Interest Rate Derivatives$4.7 billion$4.5 billionMay 31, 20222.30%One-month LIBOR
Notional Amounts
June 30, 2020December 31, 2019TermWeighted Average Fixed Interest Rate PaidVariable Interest Rate Received
CCH Interest Rate Derivatives$4.7 billion$4.5 billionMay 31, 2022 (1)2.30%One-month LIBOR
CCH Interest Rate Forward Start Derivatives$250 million$250 millionSeptember 30, 2020 (2)2.05%Three-month LIBOR
CCH Interest Rate Forward Start Derivatives$500 million$500 millionDecember 31, 2020 (2)2.06%Three-month LIBOR

(1)    Represents the maturity date.
(2)Represents the effective date. These forward start derivatives have terms of 10 years with a mandatory termination date consistent with the effective date.

The following table shows the fair value and location of our Interest Rate Derivatives on our Consolidated Balance Sheets (in millions):
September 30, 2020December 31, 2019
CCH Interest Rate DerivativesCCH Interest Rate Forward Start DerivativesTotalCCH Interest Rate DerivativesCCH Interest Rate Forward Start DerivativesTotal
Consolidated Balance Sheets Location
Derivative liabilities$(99)$0 $(99)$(32)$(8)$(40)
Non-current derivative liabilities(66)0 (66)(49)0 (49)
Total derivative liabilities$(165)$0 $(165)$(81)$(8)$(89)
 June 30, 2020 December 31, 2019
 CCH Interest Rate Derivatives CCH Interest Rate Forward Start Derivatives Total CCH Interest Rate Derivatives CCH Interest Rate Forward Start Derivatives Total
Consolidated Balance Sheets Location           
Derivative liabilities$(100) $(102) $(202) $(32) $(8) $(40)
Non-current derivative liabilities(91) —
 (91) (49) —
 (49)
Total derivative liabilities$(191)
$(102)
$(293)
$(81)
$(8)
$(89)


The following table shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in interest rate derivative loss, net on our Consolidated Statements of Operations during the three and sixnine months ended JuneSeptember 30, 2020 and 2019 (in millions):
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
CCH Interest Rate Derivatives loss $(15) $(67) $(138) $(102)
CCH Interest Rate Forward Start Derivatives loss (10) (7) (95) (7)

Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
CCH Interest Rate Derivatives loss$0 $(17)$(138)$(119)
CCH Interest Rate Forward Start Derivatives loss0 (61)(95)(68)

Liquefaction Supply Derivatives

CCL has entered into primarily index-based physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the Liquefaction Project. The remaining terms of the physical natural gas supply contracts range up to 1011 years, some of which commence upon the satisfaction of certain conditions precedent.

The forward notional for our Liquefaction Supply Derivatives was approximately 3,0943,249 TBtu and 3,153 TBtu as of JuneSeptember 30, 2020 and December 31, 2019, respectively, of which 9174 TBtu and 120 TBtu, respectively, were for a natural gas supply contract CCL has with a related party.

11

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Consolidated Balance Sheets (in millions):
  Fair Value Measurements as of (1)
Consolidated Balance Sheets Location June 30, 2020 December 31, 2019
Derivative assets $108
 $74
Derivative assets—related party 5
 3
Non-current derivative assets 159
 61
Non-current derivative assets—related party 2
 2
Total derivative assets 274

140
     
Derivative liabilities (21) (6)
Non-current derivative liabilities (69) (86)
Total derivative liabilities (90) (92)
     
Derivative asset, net $184
 $48

Fair Value Measurements as of (1)
Consolidated Balance Sheets LocationSeptember 30, 2020December 31, 2019
Derivative assets$81 $74 
Derivative assets—related party1 3 
Non-current derivative assets195 61 
Non-current derivative assets—related party0 2 
Total derivative assets277 140 
Derivative liabilities(22)(6)
Non-current derivative liabilities(81)(86)
Total derivative liabilities(103)(92)
Derivative asset, net$174 $48 
(1)Does not include collateral posted with counterparties by us of 0 and $5 million for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of June 30, 2020 and December 31, 2019, respectively.
(1)    Does not include collateral posted with counterparties by us of $8 million and $5 million for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of September 30, 2020 and December 31, 2019, respectively.

The following table shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations during the three and sixnine months ended JuneSeptember 30, 2020 and 2019 (in millions):
 Consolidated Statements of Operations Location (1)Three Months Ended June 30, Six Months Ended June 30,
 2020 2019 2020 2019
Liquefaction Supply Derivatives lossLNG revenues$(10) $(1) $(10) $—
Liquefaction Supply Derivatives gain (loss)Cost of sales(18) 3
 153
 11
Liquefaction Supply Derivatives gain (loss)Cost of sales—related party1
 (1) 2
 (3)
Consolidated Statements of Operations Location (1)Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
Liquefaction Supply Derivatives gainLNG revenues$14 $0 $4 $0 
Liquefaction Supply Derivatives gain (loss)Cost of sales(17)(114)136 (103)
Liquefaction Supply Derivatives lossCost of sales—related party(5)(1)(3)(4)
(1)Does not include the realized value associated with derivative instruments that settle through physical delivery. Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.
(1)    Does not include the realized value associated with derivative instruments that settle through physical delivery. Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

Consolidated Balance 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):
Gross Amounts RecognizedGross Amounts Offset in the Consolidated Balance SheetsNet Amounts Presented in the Consolidated Balance Sheets
Offsetting Derivative Assets (Liabilities)
As of September 30, 2020
CCH Interest Rate Derivatives$(165)$0 $(165)
Liquefaction Supply Derivatives279 (2)277 
Liquefaction Supply Derivatives(118)15 (103)
As of December 31, 2019
CCH Interest Rate Derivatives$(81)$0 $(81)
CCH Interest Rate Forward Start Derivatives(8)0 (8)
Liquefaction Supply Derivatives145 (5)140 
Liquefaction Supply Derivatives(98)6 (92)
  Gross Amounts Recognized Gross Amounts Offset in the Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets
Offsetting Derivative Assets (Liabilities)   
As of June 30, 2020      
CCH Interest Rate Derivatives $(191) $—
 $(191)
CCH Interest Rate Forward Start Derivatives (102) —
 (102)
Liquefaction Supply Derivatives 283
 (9) 274
Liquefaction Supply Derivatives (92) 2
 (90)
As of December 31, 2019      
CCH Interest Rate Derivatives $(81) $—
 $(81)
CCH Interest Rate Forward Start Derivatives (8) —
 (8)
Liquefaction Supply Derivatives 145
 (5) 140
Liquefaction Supply Derivatives (98) 6
 (92)


12

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 7—OTHER NON-CURRENT ASSETS

As of JuneSeptember 30, 2020 and December 31, 2019, other non-current assets, net consisted of the following (in millions):
September 30,December 31,
20202019
Advances and other asset conveyances to third parties to support LNG terminal$21 $19 
Operating lease assets6 7 
Tax-related payments and receivables3 3 
Information technology service prepayments3 3 
Advances made under EPC and non-EPC contracts2 14 
Contract assets, net36 0 
Other6 10 
Total other non-current assets, net$77 $56 
  June 30, December 31,
  2020 2019
Advances and other asset conveyances to third parties to support LNG terminal $20
 $19
Operating lease assets 7
 7
Tax-related payments and receivables 3
 3
Information technology service prepayments 3
 3
Advances made under EPC and non-EPC contracts —
 14
Contract assets, net 32
 —
Other 8
 10
Total other non-current assets, net $73
 $56


NOTE 8—ACCRUED LIABILITIES
 
As of JuneSeptember 30, 2020 and December 31, 2019, accrued liabilities consisted of the following (in millions): 
September 30,December 31,
20202019
Interest costs and related debt fees$101 $8 
Accrued natural gas purchases129 132 
Liquefaction Project costs45 192 
Other40 38 
Total accrued liabilities$315 $370 
  June 30, December 31,
  2020 2019
Interest costs and related debt fees $8
 $8
Accrued natural gas purchases 71
 132
Liquefaction Project costs 42
 192
Other 27
 38
Total accrued liabilities $148
 $370


NOTE 9—DEBT

As of JuneSeptember 30, 2020 and December 31, 2019, our debt consisted of the following (in millions): 
September 30,December 31,
20202019
Long-term debt:
3.520% to 7.000% senior secured notes due through 2039 and CCH Credit Facility$10,240 $10,235 
Unamortized debt issuance costs(123)(142)
Total long-term debt, net10,117 10,093 
Current debt:
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) and current portion of CCH Credit Facility249 0 
Unamortized premium, discount and debt issuance costs, net(1)0 
Total current debt248 0 
Total debt, net$10,365 $10,093 
  June 30, December 31,
  2020 2019
Long-term debt    
7.000% Senior Secured Notes due 2024 (“2024 CCH Senior Notes”) $1,250
 $1,250
5.875% Senior Secured Notes due 2025 (“2025 CCH Senior Notes”) 1,500
 1,500
5.125% Senior Secured Notes due 2027 (“2027 CCH Senior Notes”) 1,500
 1,500
3.700% Senior Secured Notes due 2029 (“2029 CCH Senior Notes”) 1,500
 1,500
4.80% Senior Secured Notes due 2039 (“4.80% CCH Senior Notes”) 727
 727
3.925% Senior Secured Notes due 2039 (“3.925% CCH Senior Notes”) 475
 475
CCH Credit Facility 3,283
 3,283
Unamortized debt issuance costs (129) (142)
Total long-term debt, net 10,106

10,093
     
Current debt    
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) 141
 —
Total debt, net $10,247
 $10,093


13

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Issuances

The following table shows the issuances of debt during the nine months ended September 30, 2020:
Maturity DateInterest RatePrincipal Amount Issued (in millions)
Three Months Ended September 30, 2020
3.52% Senior Secured Notes due 2039 (the “3.52% Senior Secured Notes”) (1)December 31, 20393.52%$769 
Nine Months Ended September 30, 2020 total$769 
(1)Proceeds of the 3.52% Senior Secured Notes were used to repay a portion of the outstanding borrowing under the CCH Credit Facility, pay costs associated with certain interest rate derivative instruments that were unwound and pay certain fees, costs and expenses incurred in connection with these transactions. The repayment of the CCH Credit Facility resulted in the recognition of debt extinguishment costs of $9 million for the three and nine months ended September 30, 2020 relating to the write off of unamortized debt discounts and issuance costs.

Credit Facilities

Below is a summary of our credit facilities outstanding as of JuneSeptember 30, 2020 (in millions):
CCH Credit Facility (1)CCH Working Capital Facility
Original facility size$8,404 $350 
Incremental commitments1,566 850 
Less:
Outstanding balance2,627 141 
Commitments terminated7,343 0 
Letters of credit issued0 293 
Available commitment$0 $766 
Interest rate on available balanceLIBOR plus 1.75% or base rate plus 0.75%LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%
Weighted average interest rate of outstanding balance1.90%1.41%
Maturity dateJune 30, 2024June 29, 2023
  CCH Credit Facility CCH Working Capital Facility
Original facility size $8,404
 $350
Incremental commitments 1,566
 850
Less:    
Outstanding balance 3,283
 141
Commitments terminated 6,687
 —
Letters of credit issued —
 392
Available commitment $—
 $667
     
Interest rate on available balance LIBOR plus 1.75% or base rate plus 0.75% LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%
Weighted average interest rate of outstanding balance 1.93% 1.43%
Maturity date 
June 30, 2024
 
June 29, 2023
(1)We prepaid $656 million of outstanding borrowings under the CCH Credit Facility during the three and nine months ended September 30, 2020 using proceeds from the issuance of the 3.52% Senior Secured Notes.


Restrictive Debt Covenants

As of JuneSeptember 30, 2020, we were in compliance with all covenants related to our debt agreements.

Interest Expense

Total interest expense, net of capitalized interest consisted of the following (in millions):
 Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
Total interest cost$117 $137 $365 $408 
Capitalized interest, including amounts capitalized as an Allowance for Funds Used During Construction(28)(47)(87)(233)
Total interest expense, net of capitalized interest$89 $90 $278 $175 
 Three Months Ended June 30, Six Months Ended June 30,
 2020 2019 2020 2019
Total interest cost$119
 $138
 $248
 $271
Capitalized interest, including amounts capitalized as an Allowance for Funds Used During Construction(29) (65) (59) (186)
Total interest expense, net of capitalized interest$90
 $73
 $189

$85

14

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Fair Value Disclosures

The following table shows the carrying amount and estimated fair value of our debt (in millions):
  June 30, 2020 December 31, 2019
  Carrying
Amount		 Estimated
Fair Value		 Carrying
Amount		 Estimated
Fair Value
Senior notes (1) $5,750
 $6,282
 $5,750
 $6,329
4.80% CCH Senior Notes (2) 727
 841
 727
 830
3.925% CCH Senior Notes (2) 475
 502
 475
 495
Credit facilities (3) 3,424
 3,424
 3,283
 3,283
 September 30, 2020December 31, 2019
 Carrying
Amount		Estimated
Fair Value		Carrying
Amount		Estimated
Fair Value
Senior notes — Level 2 (1)$5,750 $6,384 $5,750 $6,329 
Senior notes — Level 3 (2)1,971 2,144 1,202 1,325 
Credit facilities (3)2,768 2,768 3,283 3,283 
(1)Includes 2024 CCH Senior Notes, 2025 CCH Senior Notes, 2027 CCH Senior Notes and 2029 CCH Senior Notes. The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.
(2)The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 
(3)Includes CCH Credit Facility and CCH Working Capital Facility. 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.

(1)The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.
(2)The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 

(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.
CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 10—REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers during the three and sixnine months ended JuneSeptember 30, 2020 and 2019 (in millions):
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
LNG revenues (1) $620
 $119
 $963
 $131
LNG revenues—affiliate 44
 182
 234
 275
Total revenues from customers 664
 301
 1,197
 406
Net derivative losses (2) (10) (1) (10) —
Total revenues $654
 $300
 $1,187
 $406
Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
LNG revenues (1)$323 $220 $1,286 $351 
LNG revenues—affiliate106 167 340 442 
Total revenues from customers429 387 1,626 793 
Net derivative gains (2)14 0 4 0 
Total revenues$443 $387 $1,630 $793 
(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. LNG revenues during the three and six months ended June 30, 2020 included $299 million and $336 million, respectively, in revenues associated with LNG cargoes for which customers have notified us that they will not take delivery, of which $200 million would have otherwise been recognized subsequent to June 30, 2020, if the cargoes were lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended June 30, 2020 excluded $37
(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. LNG revenues during the three and nine months ended September 30, 2020 included $62 million and $398 million, respectively, in revenues associated with LNG cargoes for which customers have notified us that they will not take delivery, of which $26 million would have otherwise been recognized subsequent to September 30, 2020, if the cargoes were lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $200 million in prior period cancellations that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with the customers. 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—Derivative Instruments for additional information about our derivatives.

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

Contract Assets

The following table shows our contract assets, net, which are classified as other non-current assets, net on our Consolidated Balance Sheets (in millions):
September 30,December 31,
20202019
Contract assets, net$36 $0 
  June 30, December 31,
  2020 2019
Contract assets, net $32
 $—

15

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Contract assets represent our right to consideration for transferring goods or services to the customer under the terms of a sales contract when the associated consideration is not yet due.

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 JuneSeptember 30, 2020 and December 31, 2019:
September 30, 2020December 31, 2019
Unsatisfied
Transaction Price
(in billions)		Weighted Average Recognition Timing (years) (1)Unsatisfied
Transaction Price
(in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues$32.8 10$33.6 11
LNG revenues—affiliate1.0 121.0 13
Total revenues$33.8 $34.6 
  June 30, 2020 December 31, 2019
  Unsatisfied
Transaction Price
(in billions)		 Weighted Average Recognition Timing (years) (1) Unsatisfied
Transaction Price
(in billions)		 Weighted Average Recognition Timing (years) (1)
LNG revenues $32.9
 10 $33.6
 11
LNG revenues—affiliate 1.0
 13 1.0
 13
Total revenues $33.9
   $34.6
  
(1)
(1)    The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.


CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

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 delivery duration of one year or less.
(2)The table above excludes substantially all variable consideration under our SPAs. 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 18% and 46% of our LNG revenues from contracts included in the table above during the three months ended June 30, 2020 and 2019, respectively, and approximately 24% and 46% of our LNG revenues from contracts included in the table above during the six months ended June 30, 2020 and 2019 were related to variable consideration received from customers.
(1)We omit from the table above all performance obligations that are part of a contract that has an original expected delivery duration of one year or less.
(2)The table above excludes substantially all variable consideration under our SPAs. 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 31% and 42% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2020 and 2019, respectively, and approximately 26% and 43% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2020 and 2019, respectively, were related to variable consideration received from customers.

We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching a final investment decision on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and will be included in the transaction price above when the conditions are considered probable of being met.

16

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
NOTE 11—RELATED PARTY TRANSACTIONS

Below is a summary of our related party transactions as reported on our Consolidated Statements of Operations for the three and sixnine months ended JuneSeptember 30, 2020 and 2019 (in millions):
Three Months Ended September 30,Nine Months Ended September 30,
2020201920202019
LNG revenues—affiliate
Cheniere Marketing Agreements$106 $161 $334 $436 
Contracts for Sale and Purchase of Natural Gas and LNG0 6 6 6 
Total LNG revenues—affiliate106 167 340 442 
Cost of sales—affiliate
Contracts for Sale and Purchase of Natural Gas and LNG16 2 24 2 
Cost of sales—related party
Natural Gas Supply Agreement29 23 77 59 
Operating and maintenance expense—affiliate
Services Agreements23 15 68 36 
Operating and maintenance expense—related party
Natural Gas Transportation Agreements2 0 4 0 
General and administrative expense—affiliate
Services Agreements5 4 15 7 
 Three Months Ended June 30, Six Months Ended June 30,
 2020 2019 2020 2019
LNG revenues—affiliate       
Cheniere Marketing Agreements$38
 $182
 $228
 $275
Contracts for Sale and Purchase of Natural Gas and LNG6
 —
 6
 —
Total LNG revenues—affiliate44
 182
 234
 275
        
Cost of sales—affiliate       
Contracts for Sale and Purchase of Natural Gas and LNG2
 —
 8
 —
        
Cost of sales—related party       
Natural Gas Supply Agreement25
 26
 48
 36
        
Operating and maintenance expense—affiliate       
Services Agreements25
 16
 45
 21
        
Operating and maintenance expense—related party       
Agreements with Midship Pipeline2
 —
 2
 —
        
General and administrative expense—affiliate       
Services Agreements5
 2
 10
 3


We had $20$30 million and $27 million due to affiliates as of JuneSeptember 30, 2020 and December 31, 2019, respectively, under agreements with affiliates, as described below.


CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

Cheniere Marketing Agreements

Cheniere Marketing SPA

CCL has a fixed price SPA with Cheniere Marketing International LLP (“Cheniere Marketing”) (the “Cheniere Marketing Base SPA”) with a term of 20 years which allows Cheniere Marketing to purchase, at its option, (1) up to a cumulative total of 150 TBtu of LNG within the commissioning periods for Trains 1 through 3 and (2) any excess LNG produced by the Liquefaction Facilities that is not committed to customers under third-party SPAs. Under the Cheniere Marketing Base SPA, Cheniere Marketing may, without charge, elect to suspend deliveries of cargoes (other than commissioning cargoes) scheduled for any month under the applicable annual delivery program by providing specified notice in advance. Additionally, CCL has: (1) a fixed price SPA with an approximate term of 23 years with Cheniere Marketing which allows them to purchase volumes of approximately 15 TBtu per annum of LNG and (2) an SPA for approximately 44 TBtu of LNG with a term of up to seven years associated with the integrated production marketing gas supply agreement between CCL and EOG Resources, Inc. As of JuneSeptember 30, 2020 and December 31, 2019, CCL had 0$36 million and $57 million of accounts receivable—affiliate, respectively, under these agreements with Cheniere Marketing.

Train 3 Commissioning Letter Agreement

Under the Cheniere Marketing Base SPA, CCL entered into a letter agreement with Cheniere Marketing for the sale of commissioning cargoes from Train 3 of the Liquefaction Project. Under the agreement, CCL is required to pay Cheniere Marketing a one-time shipping fee of $1 million within 10 days after the first day of commissioning, as notified by us.

Facility Swap Agreement

We have entered into an arrangement with subsidiaries of Cheniere to provide the ability, in limited circumstances, to potentially fulfill commitments to LNG buyers in the event operational conditions impact operations at either the Sabine Pass or
17

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Corpus Christi liquefaction facilities. The purchase price for such cargoes would be (i) 115% of the applicable natural gas feedstock purchase price or (ii) a free-on-board U.S. Gulf Coast LNG market price, whichever is greater.

Services Agreements

Gas and Power Supply Services Agreement (“G&P Agreement”)

CCL has a G&P Agreement with Cheniere Energy Shared Services, Inc. (“Shared Services”), a wholly owned subsidiary of Cheniere, pursuant to which Shared Services will manage the gas and power procurement requirements of CCL. The services include, among other services, exercising the day-to-day management of CCL’s natural gas and power supply requirements, negotiating agreements on CCL’s behalf and providing other administrative services. Prior to the substantial completion of each Train of the Liquefaction Facilities, no monthly fee payment is required except for reimbursement of operating expenses. After substantial completion of each Train of the Liquefaction Facilities, for services performed while the Liquefaction Facilities is operational, CCL will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $125,000 (indexed for inflation) for services with respect to such Train.

Operation and Maintenance Agreements (“O&M Agreements”)

CCL has an O&M Agreement (“CCL O&M Agreement”) with Cheniere LNG O&M Services, LLC (“O&M Services”), a wholly owned subsidiary of Cheniere, pursuant to which CCL receives all of the necessary services required to construct, operate and maintain the Liquefaction Facilities. The services to be provided include, among other services, preparing and maintaining staffing plans, identifying and arranging for procurement of equipment and materials, overseeing contractors, administering various agreements, information technology services and other services required to operate and maintain the Liquefaction Facilities. Prior to the substantial completion of each Train of the Liquefaction Facilities, no monthly fee payment is required except for reimbursement of operating expenses. After substantial completion of each Train of the Liquefaction Facilities, for services performed while the Liquefaction Facilities is operational, CCL will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $125,000 (indexed for inflation) for services with respect to such Train.

CCP has an O&M Agreement (“CCP O&M Agreement”) with O&M Services pursuant to which CCP receives all of the necessary services required to construct, operate and maintain the Corpus Christi Pipeline. The services to be provided include, among other services, preparing and maintaining staffing plans, identifying and arranging for procurement of equipment and materials, overseeing contractors, information technology services and other services required to operate and maintain the Corpus Christi Pipeline. CCP is required to reimburse O&M Services for all operating expenses incurred on behalf of CCP.

Management Services Agreements (“MSAs”)

CCL has a MSA with Shared Services pursuant to which Shared Services manages the construction and operation of the Liquefaction Facilities, excluding those matters provided for under the G&P Agreement and the CCL O&M Agreement. The services include, among other services, exercising the day-to-day management of CCL’s affairs and business, managing CCL’s regulatory matters, preparing status reports, providing contract administration services for all contracts associated with the Liquefaction Facilities and obtaining insurance. Prior to the substantial completion of each Train of the Liquefaction Facilities, no monthly fee payment is required except for reimbursement of expenses. After substantial completion of each Train, CCL will pay, in addition to the reimbursement of related expenses, a monthly fee equal to 3% of the capital expenditures incurred in the previous month and a fixed monthly fee of $375,000 for services with respect to such Train.


CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

CCP has a MSA with Shared Services pursuant to which Shared Services manages CCP’s operations and business, excluding those matters provided for under the CCP O&M Agreement. The services include, among other services, exercising the day-to-day management of CCP’s affairs and business, managing CCP’s regulatory matters, preparing status reports, providing contract administration services for all contracts associated with the Corpus Christi Pipeline and obtaining insurance. CCP is required to reimburse Shared Services for the aggregate of all costs and expenses incurred in the course of performing the services under the MSA.

18

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Natural Gas Supply Agreement

CCL has entered intois party to a natural gas supply contractagreement with a related party in the ordinary course of business, to obtain feed gas for the operation of the Liquefaction Project through March 20222022. In addition to the amounts recorded on our Consolidated Statements of Operations in the table above, CCL recorded accrued liabilities—related party of $13 million and $3 million, derivative assets—related party of $1 million and $3 million and non-current derivative assets—related party of 0 and $2 million as of September 30, 2020 and December 31, 2019, respectively, related to this agreement.

Natural Gas Transportation Agreements

Agreements with Related Party

CCL is party to natural gas transportation agreements with a related party in the ordinary course of business. CCL recorded $25 million and $26 million in costbusiness for the operation of sales—related party during the three months ended June 30, 2020 and 2019, respectively and $48 million and $36 million in cost of sales—related party during the six months ended June 30, 2020 and 2019, respectively, under this contract. Of this amount, $8 million and $3 million was included in accrued liabilities—related party as of June 30, 2020 and December 31, 2019, respectively. CCL also has recorded derivative assets—related party of $5 million and $3 million as of June 30, 2020 and December 31, 2019, respectively, and non-current derivative assets—related party of $2 million as of both June 30, 2020 and December 31, 2019, related to this contract.

Agreements with Midship Pipeline

CCL has entered into a transportation precedent agreement and a negotiated rate agreement with Midship Pipeline Company, LLC (“Midship Pipeline”) to secure firm pipeline transportation capacityLiquefaction Project, for a period of 10 years beginning in May 2020. In March 2020, we along with CCL, entered into a guaranty agreement whereby we will absolutely and irrevocably guarantee CCL’s obligation underaddition to the transportation precedent agreement with Midship Pipeline.amounts recorded on our Consolidated Statements of Operations in the table above, CCL recorded $2 million in operating and maintenance expense—accrued liabilities—related party during both the threeof $1 million and six months ended June0 as of September 30, 2020 and $1 million of accrued liabilities—December 31, 2019, respectively, related party as of June 30, 2020 underto this agreement.

Natural Gas Transportation AgreementAgreements with Cheniere Corpus Christi Liquefaction Stage III, LLC

Cheniere Corpus Christi Liquefaction Stage III, LLC, a wholly owned subsidiary of Cheniere, has a transportation precedent agreement with CCP to secure firm pipeline transportation capacity for the transportation of natural gas feedstock to the expansion of the Corpus Christi LNG terminal it is constructing adjacent to the Liquefaction Project. The agreement will have a primary term of 20 years from the service commencement date with right to extend the term for 2 successive five-yearfive-year terms.

Contracts for Sale and Purchase of Natural Gas and LNG

CCL has an agreement with Sabine Pass Liquefaction, LLC that allows them to sell and purchase natural gas with each other. Natural gas purchased under this agreement is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. Natural gas sold under this agreement is recorded as LNG revenues—affiliate.

CCL also has an agreement with Midship Pipeline Company, LLC that allows them to sell and purchase natural gas with each other.

Land Agreements

Lease Agreements

CCL has agreements with Cheniere Land Holdings, LLC (“Cheniere Land Holdings”), a wholly owned subsidiary of Cheniere, to lease the land owned by Cheniere Land Holdings for the Liquefaction Facilities. The total annual lease payment is $0.6 million, and the terms of the agreements range from three to seven years.


CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

Easement Agreements

CCL has agreements with Cheniere Land Holdings which grant CCL easements on land owned by Cheniere Land Holdings for the Liquefaction Facilities. The total annual payment for easement agreements is $0.1 million, excluding any previously paid one-time payments, and the terms of the agreements range from three to five years.
Dredge Material Disposal Agreement

CCL has a dredge material disposal agreement with Cheniere Land Holdings that terminates in 2042 which grants CCL permission to use land owned by Cheniere Land Holdings for the deposit of dredge material from the construction and maintenance of the Liquefaction Facilities. Under the terms of the agreement, CCL will pay Cheniere Land Holdings $0.50 per cubic yard of dredge material deposits up to 5.0 million cubic yards and $4.62 per cubic yard for any quantities above that.
19

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
Tug Hosting Agreement

In February 2017, CCL entered into a tug hosting agreement with Corpus Christi Tug Services, LLC (“Tug Services”), a wholly owned subsidiary of Cheniere, to provide certain marine structures, support services and access necessary at the Liquefaction Facilities for Tug Services to provide its customers with tug boat and marine services. Tug Services is required to reimburse CCL for any third party costs incurred by CCL in connection with providing the goods and services.

State Tax Sharing Agreements
CCL has a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which CCL and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, CCL will pay to Cheniere an amount equal to the state and local tax that CCL would be required to pay if CCL’s state and local tax liability were calculated on a separate company basis. There have been 0 state and local taxes paid by Cheniere for which Cheniere could have demanded payment from CCL under this agreement; therefore, Cheniere has not demanded any such payments from CCL. The agreement is effective for tax returns due on or after May 2015.

CCP has a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which CCP and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, CCP will pay to Cheniere an amount equal to the state and local tax that CCP would be required to pay if CCP’s state and local tax liability were calculated on a separate company basis. There have been 0 state and local taxes paid by Cheniere for which Cheniere could have demanded payment from CCP under this agreement; therefore, Cheniere has not demanded any such payments from CCP. The agreement is effective for tax returns due on or after May 2015.

Equity Contribution Agreements

Equity Contribution Agreement

In May 2018, we amended and restated the existing equity contribution agreement with Cheniere (the “Equity Contribution Agreement”) pursuant to which Cheniere agreed to provide cash contributions up to approximately $1.1 billion, not including $2.0 billion previously contributed under the original equity contribution agreement. As of JuneSeptember 30, 2020, we have received $703 million in contributions under the Equity Contribution Agreement and Cheniere has posted $313$182 million of letters of credit on our behalf. Cheniere is only required to make additional contributions under the Equity Contribution Agreement after the commitments under the CCH Credit Facility have been reduced to 0 and to the extent cash flows from operations of the Liquefaction Project are unavailable for Liquefaction Project costs.


CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 12—CUSTOMER CONCENTRATION
  
The following table shows customers with revenues of 10% or greater of total revenues from external customers and customers with accounts receivable, net and contract assets, net balances of 10% or greater of total accounts receivable, net and contract assets, net from external customers:
  Percentage of Total Revenues from External Customers Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers
  Three Months Ended June 30, Six Months Ended June 30, June 30, December 31,
  2020 2019 2020 2019 2020 2019
Customer A 32% 38% 39%
34% 22% 38%
Customer B 10% —% 12%
—% 14% —%
Customer C 19% —% 17% —% 12% 39%
Customer D 10% 19% 11% 17% * —%
Customer E 14% —% * —% 13% —%
Percentage of Total Revenues from External CustomersPercentage of Accounts Receivable, Net and Contract Assets, Net from External Customers
Three Months Ended September 30,Nine Months Ended September 30,September 30,December 31,
202020192020201920202019
Customer A17%61%33%51%*38%
Customer B*0%*0%23%0%
Customer C14%29%16%18%31%39%
Customer D***12%00%
Customer E12%0%*0%00%
Customer F13%0%*0%*0%
* Less than 10%

20

CHENIERE CORPUS CHRISTI HOLDINGS, LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)
NOTE 13—SUPPLEMENTAL CASH FLOW INFORMATION

The following table provides supplemental disclosure of cash flow information (in millions):
Nine Months Ended September 30,
20202019
Cash paid during the period for interest, net of amounts capitalized$192 $137 
Non-cash distributions to affiliates for conveyance of assets2 0 
 Six Months Ended June 30,
 2020 2019
Cash paid during the period for interest, net of amounts capitalized$179
 $—


The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $29$52 million and $269$215 million as of JuneSeptember 30, 2020 and 2019, respectively.

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

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 terminal, 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 relating to the construction of our Trains and pipeline, 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 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 and pipelines, including the financing of such Trains and 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 the outbreak of COVID-19 and its impact on our business and operating results, including any customers not taking delivery of LNG cargoes, the ongoing credit worthiness of our contractual counterparties, any disruptions in our operations or construction of our Trains and the health and safety of Cheniere’s 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 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”
22

in our annual report on Form 10-K for the fiscal year ended December 31, 2019 and our quarterly report on Form 10-Q for the quarterly period ending March 31, 2020. 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 
•Impact of COVID-19 and Market Environment
•Liquidity and Capital Resources
•Results of Operations 
•Off-Balance Sheet Arrangements  
•Summary of Critical Accounting Estimates 
•Recent Accounting Standards

Overview of Business

We are operating and constructing a natural gas liquefaction and export facility (the “Liquefaction Facilities”) and operating a 23-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 Liquefaction Facilities, the “Liquefaction Project”) near Corpus Christi, Texas, through our subsidiaries CCL and CCP, respectively.

We are currently operating two Trains and one additional Train is undergoing commissioning for a total production capacity of approximately 15 mtpa of LNG. The Liquefaction Project, once fully constructed, will contain 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.

Overview of Significant Events

Our significant events since January 1, 2020 and through the filing date of this Form 10-Q include the following:
Strategic
•In August 2020, we entered into an arrangement with subsidiaries of Cheniere to provide the ability, in limited circumstances, to potentially fulfill commitments to LNG buyers in the event operational conditions impact operations at either the Sabine Pass or Corpus Christi liquefaction facilities. The purchase price for such cargoes would be (i) 115% of the applicable natural gas feedstock purchase price or (ii) a free-on-board U.S. Gulf Coast LNG market price, whichever is greater.
Operational
•As of JulyOctober 31, 2020, more than 150180 cumulative LNG cargoes totaling over 1012 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Project.
•In October 2020, feed gas was introduced to Train 3 of the Liquefaction Project.
23

Financial
•In May 2020, the date of first commercial delivery was reached under the 20-year SPAs with PT Pertamina (Persero), Naturgy LNG GOM, Limited, Woodside Energy Trading Singapore Pte Ltd, Iberdrola, S.A. and Électricité de France, S.A. relating to Train 2 of the Liquefaction Project.
•In August 2020, Moody’s Investors Service upgraded its rating of our senior secured debt from Ba1 (Positive Outlook) to Baa3.

•In August 2020, we issued an aggregate principal amount of approximately $769 million of 3.52% Senior Secured Notes due 2039 (the “3.52% CCH Senior Secured Notes”). The net proceeds of these notes were used to repay a portion of the outstanding borrowings under our amended and restated credit facility (the “CCH Credit Facility”), pay costs associated with certain interest rate derivative instruments that were settled and pay certain fees, costs and expenses incurred in connection with these transactions.

Impact of COVID-19 and Market Environment

The business environment in which we operate has been impacted by the recent downturn in the energy market as well as the outbreak of COVID-19 and its progression into a pandemic in March 2020. As a result of these developments, our growth

estimates for LNG in 2020 have moderated from previous expectations. Annual LNG demand grew by approximately 13% in 2019 to approximately 360 mtpa. In a report published in the month of April 2020, IHS Markit projected LNG demand in 2020 to reach 363 mtpa, down from a pre-COVID-19 estimate of approximately 377 mtpa. This implies a year-over-year rate of growth of below 1% in 2020 compared to an implied pre-COVID-19 year-over-year growth estimate of approximately 5%. While worldwide demand increased by approximately 5%3% during the sixnine months ended JuneSeptember 30, 2020 compared to the comparable period of 2019, we expectcontinue to potentially see year-over-year declinesbe cautiously optimistic on the outlook. Global economic indicators point to a start of a recovery in some future months as reduced economic activity affectsparts of the world but risks from second waves of infections and re-instatement of lockdowns could exert bearish pressures on the market. LNG demand and high storage inventory levels reduce the need for imports. The robust LNG supply additions over the past several years, alongimporters had to cope with warmer winters and now strict virus containment measures throughout the first and second quarters of 2020, which negatively impacted gas and LNG demand and resulted in many buyers having to resort to extraordinary measures to manage LNG supply purchases and contractual commitments. Some of these measures included cargo deferrals and cancellations. As the market started to rebalance and storage inventories started to normalize, prices today have exerted downward pressure on global gas prices.recovered from their second quarter lows. As an example, the Dutch Title Transfer Facility (“TTF”), a virtual trading point for natural gas in the Netherlands, averaged $1.76 during the three months ended June 30, 2020, 60% lowersettled October at $4.23/MMBtu, which is $3.09/MMBtu higher than the comparable period of 2019, while theJune 2020 settlement. The Japan KoreanKorea Marker (“JKM”), an LNG benchmark price assessment for spot physical cargoes delivered ex-ship into certain key markets in Asia, averaged $2.68 during the three months ended June 30, 2020, 50% lowersettled October at $4.31/MMBtu, which is $2.25/MMBtu higher than the comparable period of 2019. As a result of the weaker LNG market environment, as well as customer-specific variables, we have recently experienced an increase in theits July price posting. The number of LNG cargoes for which our customers have notified us that they will not take delivery. Whiledelivery have reduced from this may impact our expected LNG production, wesummer, a sign that the market is continuing to adjust and rebalance towards equilibrium. We do not expect itthese events to have a material adverse impact on our forecasted financial results for 2020, due to the highly contracted nature of our business and the fact that customers continue to be obligated to pay fixed fees for cargoes in relation to which they have exercised their contractual right to cancel. As such, during the three and sixnine months ended JuneSeptember 30, 2020, we recognized $299$62 million and $336$398 million, respectively, in revenues associated with LNG cargoes for which customers have notified us that they would not take delivery, of which $200$26 million would have otherwise been recognized subsequent to JuneSeptember 30, 2020, if the cargoes were lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $200 million in prior period cancellations that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with the customers. We experienced decreased revenues during the three months ended September 30, 2020 because we recognized accelerated revenues associated with LNG cargoes that were scheduled for delivery during the current quarter in the prior quarter, when the customers notified us that they will not take delivery of such cargoes.

In addition, in response to the COVID-19 pandemic, Cheniere has modified certain business and workforce practices to protect the safety and welfare of its employees who continue to work at its facilities and offices worldwide, as well as implemented certain mitigation efforts to ensure business continuity. In March 2020, Cheniere began consulting with a medical advisor, and implemented social distancing through revised shift schedules, work from home policies and designated remote work locations where appropriate, restricted non-essential business travel and began requiring self-screening for employees and contractors. In April 2020, Cheniere began providing temporary housing for its workforce for our facilities, implemented temperature testing, incorporated medical and social workers to support employees, enforced prior self-isolation and screening for temporary housing and implemented marine operations with zero contact during loading activities. These measures have resulted in increased costs. While response measures continue to evolve and in certainmost cases moderate,have moderated or ceased, we
24

expect Cheniere to incur incremental operating costs associated with business continuity and protection of its workforce until the risks associated with the pandemic diminish. As of June 30, 2020, weWe have incurred approximately $26$5 million and $30 million of such costs.costs during the three and nine months ended September 30, 2020, respectively.

Liquidity and Capital Resources
 
The following table provides a summary of our liquidity position at JuneSeptember 30, 2020 and December 31, 2019 (in millions):
September 30,December 31,
20202019
Cash and cash equivalents$— $— 
Restricted cash designated for the Liquefaction Project145 80 
Available commitments under the following credit facilities:
CCH Credit Facility— — 
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)766 729 
 June 30, December 31,
 2020 2019
Cash and cash equivalents$—
 $—
Restricted cash designated for the Liquefaction Project101
 80
Available commitments under the following credit facilities:   
CCH Credit Facility—
 —
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)667
 729


Corpus Christi LNG Terminal

Liquefaction Facilities

We are currently operating two Trains and one marine berth at the Liquefaction Project, commissioning one additional Train and constructing an additional marine berth. We have received authorization from the FERC to site, construct and operate Trains 1 through 3 of the Liquefaction Project. We completed construction of Trains 1 and 2 of the Liquefaction Project and commenced commercial operating activities in February 2019 and August 2019, respectively. The following table summarizes the project completion and construction status of Train 3 of the Liquefaction Project, including the related infrastructure, as of JuneSeptember 30, 2020:
Train 3
Train 3
Overall project completion percentage90.5%96.7%
Completion percentage of:
Engineering100.0%
Procurement100.0%
Subcontract work83.2%98.2%
Construction77.5%91.1%
Expected date of substantial completion1H1Q 2021

The DOE has authorized the export of domestically produced LNG by vessel from the Corpus Christi LNG terminal to FTA countries for a 25-year term and to non-FTA countries for a 20-year term, both of which commenced in June 2019,through December 31 ,2050, up to a combined total of the equivalent of 767 Bcf/yr (approximately 15 mtpa) of natural gas. The terms of each of these authorizations begin on the earlier of the date of first export thereunder or the date specified in the particular order, which ranges from seven to 10 years from the date the order was issued.

An application was filed in September 2019 to authorize additional exports from the Liquefaction 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 Liquefaction 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 Liquefaction Project of the volumes contemplated in the application. DOE’s authorization forIn April 2020, the DOE issued an order authorizing CCL to export to FTA countries has been granted. The DOErelated 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 Liquefaction Project from the currently authorized level to approximately 875.16 Bcf/yr was also submitted to the FERC and is currently pending before the DOE.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 19 years (plus extension rights) with nine third parties for Trains 1 through 3 of the Liquefaction Project. Under these SPAs, the customers will purchase LNG from CCL on a 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
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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 Liquefaction 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 $1.4 billion for Trains 1 and 2 and further increasing to approximately $1.8 billion following the substantial completion of Train 3 of the Liquefaction Project.

In addition, Cheniere Marketing International LLP (“Cheniere Marketing”) has agreements with CCL to purchase: (1) approximately 15 TBtu per annum of LNG with an approximate term of 23 years, (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 term of up to seven years associated with the integrated production marketing (“IPM”) gas supply agreement between CCL and EOG.
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 Liquefaction 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 Liquefaction Project. As of JuneSeptember 30, 2020, CCL had secured up to approximately 2,9353,026 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to 1011 years, a portion of which is subject to the achievement of certain project milestones and other conditions precedent.

A portion of the natural gas feedstock transactions for CCL 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 Oil, Gas and Chemicals, Inc. (“Bechtel”) for the engineering, procurement and construction of Trains 1 through 3 of the Liquefaction 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 CCL to enter into a change order, or CCL agrees with Bechtel to a change order.

The total contract price of the EPC contract for Train 3, which is currently under construction, is approximately $2.4 billion, reflecting amounts incurred under change orders through JuneSeptember 30, 2020. As of JuneSeptember 30, 2020, we have incurred $2.2$2.3 billion under this contract.
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Capital Resources

We expect to finance the construction costs of the Liquefaction Project from one or more of the following: operating cash flows from CCL and CCP, project debt and equity contributions from Cheniere. The following table provides a summary of our capital resources from borrowings and available commitments for the Liquefaction Project, excluding any equity contributions, at JuneSeptember 30, 2020 and December 31, 2019 (in millions):
  June 30, December 31,
  2020 2019
Senior notes (1) $6,952
 $6,952
Credit facilities outstanding balance (2) 3,424
 3,283
Letters of credit issued (2) 392
 471
Available commitments under credit facilities (2) 667
 729
Total capital resources from borrowings and available commitments (3) $11,435
 $11,435
September 30,December 31,
 20202019
Senior notes (1)$7,721 $6,952 
Credit facilities outstanding balance (2)2,768 3,283 
Letters of credit issued (2)293 471 
Available commitments under credit facilities (2)766 729 
Total capital resources from borrowings and available commitments (3)$11,548 $11,435 
(1)Includes 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 and 3.925% Senior Secured Notes due 2039 (collectively, the “CCH Senior Notes”).
(2)Includes CCH Credit Facility and CCH Working Capital Facility.
(3)Does not include additional borrowings or contributions by our indirect parents which may be used for the Liquefaction Project.
(1)Includes 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 the 3.52% CCH Senior Secured Notes (collectively, the “CCH Senior Notes”).
(2)Includes CCH Credit Facility and CCH Working Capital Facility.
(3)Does not include additional borrowings or contributions by our indirect parents which may be used for the Liquefaction Project.

CCH Senior Notes

The CCH Senior Notes are jointly and severally guaranteed by each of our consolidated subsidiaries, CCL, CCP and CCP GP (each a “Guarantor” and collectively, the “Guarantors”). The indentures governing the CCH Senior Notes contain customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our 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 our restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries to us or any of our 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 us and our restricted subsidiaries taken as a whole; or permit any 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 our senior secured obligations, ranking senior in right of payment to any and all of our future indebtedness that is subordinated to the CCH Senior Notes and equal in right of payment with our 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 our assets and the assets of the CCH Guarantors.

At any time prior to six months before the respective dates of maturity for each of the CCH Senior Notes, we 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, we 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.
The Guarantors’ guarantees are full and unconditional, subject to certain release provisions including (1) the sale, exchange, disposition or transfer (by merger, consolidation or otherwise) of all or substantially all of the capital stock or the assets of the Guarantors, (2) the designation of the Guarantor as an “unrestricted subsidiary” in accordance with the indentures governing the CCH Senior Notes (the “CCH Indentures”), (3) upon the legal defeasance or covenant defeasance or discharge of obligations under the CCH Indentures and (4) the release and discharge of the Guarantors pursuant to the Common Security and Account Agreement. In the event of a default in payment of the principal or interest by us, whether at maturity of the CCH Senior Notes or by declaration of acceleration, call for redemption or otherwise, legal proceedings may be instituted against the Guarantors to enforce the guarantee.
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The rights of holders of the CCH Senior Notes against the Guarantors may be limited under the U.S. Bankruptcy Code or federal or state fraudulent transfer or conveyance law. Each guarantee contains a provision intended to limit the Guarantor’s liability to the maximum amount that it could incur without causing the incurrence of obligations under its guarantee to be a fraudulent conveyance or transfer under U.S. federal or state law. However, there can be no assurance as to what standard a court will apply in making a determination of the maximum liability of the Guarantors. Moreover, this provision may not be effective to protect the guarantee from being voided under fraudulent conveyance laws. There is a possibility that the entire guarantee may be set aside, in which case the entire liability may be extinguished.

Summarized financial information about us and the Guarantors as a group (the “Obligor Group”) is omitted herein because such information would not be materially different from our Consolidated Financial Statements.

The CCH Senior Notes are our senior secured obligations, ranking senior in right of payment to any and all of our future indebtedness that is subordinated to the CCH Senior Notes and equal in right of payment with our 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 our assets and the assets of the CCH Guarantors.

The security interests in our assets and the assets of the CCH Guarantors are subject to release provisions including (1) upon satisfaction and discharge of the CCH Indentures, (2) upon the legal defeasance or covenant defeasance with respect to the applicable CCH Senior Notes or (3) upon payment in full in cash of the applicable CCH Senior Notes and all other related obligations that are outstanding, due and payable at the time the CCH Senior Notes are paid full in cash; and in accordance with the Common Security and Account Agreement governing the parties to the CCH Senior Notes.


CCH Credit Facility

In May 2018, we amended and restated the CCH Credit Facility to increase total commitments under the CCH Credit Facility from $4.6 billion to $6.1 billion. Our obligations under the CCH Credit Facility are secured by a first priority lien on substantially all of our assets and the assets of our subsidiaries and by a pledge by CCH HoldCo I of its limited liability company interests in us. AsThere were no available commitments under the CCH Credit Facility as of both JuneSeptember 30, 2020 and December 31, 2019, we2019. We had no available commitments$2.6 billion and $3.3 billion of loans outstanding under the CCH Credit Facility.Facility as of September 30, 2020 and December 31, 2019, respectively.

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 Liquefaction 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 Liquefaction 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, we are required to hedge not less than 65% of the variable interest rate exposure of our senior secured debt. We are restricted from making certain distributions under agreements governing our indebtedness generally until, among other requirements, the completion of the construction of Trains 1 through 3 of the Liquefaction 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

In June 2018, we amended and restated the CCH Working Capital Facility to increase total commitments under the CCH Working Capital Facility from $350 million to $1.2 billion. The CCH Working Capital Facility is intended to be used for loans (“CCH Working Capital Loans”) and the issuance of letters of credit for certain working capital requirements related to developing and operating the Liquefaction Project and for related business purposes. Loans under the CCH Working Capital Facility are guaranteed by the Guarantors. We 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 JuneSeptember 30, 2020 and December 31, 2019, we had $667 $766
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million and $729 million of available commitments, $392$293 million and $471 million aggregate amount of issued letters of credit and $141 million and zero of loans outstanding under the CCH Working Capital Facility, respectively.

The CCH Working Capital Facility matures on June 29, 2023, and we 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. We are 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. Our obligations under the CCH Working Capital Facility are secured by substantially all of our assets and the assets of the Guarantors as well as all of our membership interests and the membership interest in each of the Guarantors on a pari passu basis with the CCH Senior Notes and the CCH Credit Facility.

Equity Contribution Agreement

In May 2018, we amended and restated the existing equity contribution agreement with Cheniere (the “Equity Contribution Agreement”) pursuant to which Cheniere agreed to provide cash contributions up to approximately $1.1 billion, not including $2.0 billion previously contributed under the original equity contribution agreement. As of JuneSeptember 30, 2020, we have received $703 million in contributions under the Equity Contribution Agreement and Cheniere has posted $313$182 million of letters of credit on our behalf under its revolving credit facility. Cheniere is only required to make additional contributions under the Equity Contribution Agreement after the commitments under the CCH Credit Facility have been reduced to zero and to the extent cash flows from operations of the Liquefaction Project are unavailable for Liquefaction Project costs.


Restrictive Debt Covenants

As of JuneSeptember 30, 2020, we were in compliance with all covenants related to our debt agreements.

LIBOR

The use of LIBOR is expected to be phased out by the end of 2021. 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 to workworking with our lenders and counterparties to pursue any amendments to our debt and derivative agreements that are currently subject to LIBOR 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 sixnine months ended JuneSeptember 30, 2020 and 2019 (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,Nine Months Ended September 30,
2020 201920202019
Operating cash flows$87
 $(53)Operating cash flows$261 $(41)
Investing cash flows(352) (842)Investing cash flows(587)(1,257)
Financing cash flows286
 885
Financing cash flows391 1,141 
   
Net increase (decrease) in cash, cash equivalents and restricted cash21
 (10)Net increase (decrease) in cash, cash equivalents and restricted cash65 (157)
Cash, cash equivalents and restricted cash—beginning of period80
 289
Cash, cash equivalents and restricted cash—beginning of period80 289 
Cash, cash equivalents and restricted cash—end of period$101
 $279
Cash, cash equivalents and restricted cash—end of period$145 $132 
Operating Cash Flows

Operating cash flows during the sixnine months ended JuneSeptember 30, 2020 and 2019 were net inflows of $87$261 million and net outflows of $53$41 million, respectively. The increase in operating cash net inflows was primarily due to increased cash
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receipts from the sale of LNG cargoes, as a result of the commencement of operations of Trains 1 and 2 of the Liquefaction Project in February 2019 and August 2019, respectively, and from increased revenues related to LNG cargoes for which customers have notified us that they will not take delivery.respectively.

Investing Cash Flows

Investing cash net outflows during the sixnine months ended JuneSeptember 30, 2020 and 2019 were $352$587 million and $842$1,257 million, respectively, and were primarily used to fund the construction costs for the Liquefaction Project. These costs are capitalized as construction-in-process until achievement of substantial completion.

Financing Cash Flows

Financing cash net inflows during the sixnine months ended JuneSeptember 30, 2020 were $286$391 million, primarily as a result of:
•issuance of an aggregate principal amount of $769 million of the 3.52% CCH Senior Secured Notes, which the proceeds were partly used to repay a portion of the outstanding borrowings under the CCH Credit Facility;
•$141 million of borrowings and $656 million of repayments under the CCH Working Capital Facility;
•$9 million of debt issuance costs related to the issuance of the 3.52% CCH Senior Secured Notes; and
•$145 million of equity contributions from Cheniere.

Financing cash net inflows during the sixnine months ended JuneSeptember 30, 2019 were $885$1,141 million, primarily as a result of:
•$982981 million of borrowings and $797 million of repayments under the CCH Credit Facility;
•
$390
•$481 million of borrowings and $558 million of repayments under the CCH Working Capital Facility; and $649 million of repayments under the CCH Working Capital Facility;
•issuance of an aggregate principal amount of $727 million of the 4.80% Senior Secured Notes due 2039 (the “4.80% CCH Senior Notes”), which was used to prepay a portion of the outstanding balance of the CCH Credit Facility;
•$5 million of debt issuance costs primarily related to up-front fees paid upon the closing of the 4.80% CCH Senior Notes; and
•$403 million of equity contributions from Cheniere.

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•
$72 million of equity contributions from Cheniere.


Results of Operations

The following charts summarize the number of Trains that were in operation during the year ended December 31, 2019 and the sixnine months ended JuneSeptember 30, 2020 and total revenues and total LNG volumes loaded (including both operational and commissioning volumes) during the sixnine months ended JuneSeptember 30, 2020 and 2019:
chart-c8261c933064e350b2aa02.jpgcch-20200930_g2.jpg

chart-be969a28a19cfd29a56.jpgchart-e219e854ab3d1887c77.jpgcch-20200930_g3.jpgcch-20200930_g4.jpg
Our consolidated net incomeloss was $156$88 million infor the three months ended JuneSeptember 30, 2020, compared to net loss of $189$273 million in the three months ended JuneSeptember 30, 2019. This $345$185 million increasedecrease in net incomeloss in 2020 was primarily the result of accelerated revenues recognized(1) additional LNG volume available to be sold from LNG cargoesadditional Trains that have reached substantial completion between the periods, a portion of which the customers elected not to take delivery but were required to pay a fixed fee with respect to the contracted volumes, (2) decreased losses on commodity derivatives to secure natural gas feedstock for whichthe Liquefaction Project and (3) decreased interest rate derivative losses, partially offset by the impact of prior period elections by our long-term SPA customers have notified us that they willto exercise their contractual right to not take delivery and increased income from operations dueof LNG cargoes that were scheduled to an additional Train in operation.be delivered this quarter.

Our consolidated net income was $105$17 million infor the sixnine months ended JuneSeptember 30, 2020, compared to net loss of $260$533 million in the sixnine months ended JuneSeptember 30, 2019. This $365$550 million increase in net income in 2020 was primarily the result of increased income from operations due to an additional TrainTrains in operation and accelerated revenues recognized from LNG cargoesincreased gains on commodity derivatives to secure natural gas feedstock for the Liquefaction Project, which the customers have notified us that they will not take delivery, which werewas partially offset by increased interest rate derivative loss, net and interest expense, net of capitalized interest.interest and increased interest rate derivative losses.


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We enter into derivative instruments to manage our exposure to changing interest rates and commodity-related marketing and price risk. Derivative instruments are reported at fair value on our Consolidated Financial Statements. In some cases, the underlying transactions economically hedged receive accrual accounting treatment, 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, use of derivative instruments may increase the volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant factors.

Revenues
Three Months Ended September 30,Nine Months Ended September 30,
(in millions, except volumes)20202019Change20202019Change
LNG revenues$337 $220 $117 $1,290 $351 $939 
LNG revenues—affiliate106 167 (61)340 442 (102)
Total revenues$443 $387 $56 $1,630 $793 $837 
LNG volumes recognized as revenues (in TBtu)65 87 (22)264 164 100 
 Three Months Ended June 30, Six Months Ended June 30,
(in millions, except volumes)2020 2019 Change 2020 2019 Change
LNG revenues$610
 $118
 $492
 $953
 $131
 $822
LNG revenues—affiliate44
 182
 (138) 234
 275
 (41)
Total revenues$654
 $300
 $354
 $1,187
 $406
 $781
            
LNG volumes recognized as revenues (in TBtu)71
 56
 15
 199
 77
 122

We began recognizing LNG revenues from the Liquefaction Project following the substantial completion and the commencement of operating activities of Trains 1 and 2 in February 2019 and August 2019, respectively. The additional TrainTrains in operation between the periods resulted in additional revenue from the increased volume of LNG sold.revenue. LNG revenues during the three and sixnine months ended JuneSeptember 30, 2020 also included $299$62 million and $336$398 million, respectively, in revenues associated with LNG cargoes for which customers have notified us that they will not take delivery, of which $200$26 million would have otherwise been recognized subsequent to JuneSeptember 30, 2020, if the cargoes were lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended JuneSeptember 30, 2020 excluded $37$200 million in prior period cancellations that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with the customers. AsWe experienced decreased revenues during the three months ended September 30, 2020 because we have recognized accelerated revenues associated with LNG cargoes that were scheduled for whichdelivery during the current quarter in the prior quarter, when the customers have notified us that they will not take delivery we may expect decreased revenues in future periods for which the deliveries would have occurred.of such cargoes. We expect our LNG revenues to increase in the future upon Train 3 of the Liquefaction Project becoming operational.

Also included in LNG revenues are the sale of unutilized natural gas procured for the liquefaction process and gains and losses from derivative instruments, which include the realized value associated with a portion of derivative instruments that settle through physical delivery and the sale of unutilized natural gas procured for the liquefaction process.delivery. We recognized revenues of $44$97 million and $51$9 million during the three months ended JuneSeptember 30, 2020 and 2019, respectively, and $51$148 million and $64$73 million during the sixnine months ended JuneSeptember 30, 2020 and 2019, respectively, related to derivative instruments and other revenues from these transactions.

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 months ended JuneSeptember 30, 2019, we realized offsets to LNG terminal costs of $8$74 million corresponding to 320 TBtu of LNG that were related to the sale of commissioning cargoes. During the sixnine months ended JuneSeptember 30, 2019, we realized offsets to LNG terminal costs of $82$156 million corresponding to 1838 TBtu of LNG that were related to the sale of commissioning cargoes. We did not realize any offsets to LNG terminal costs during the three and sixnine months ended JuneSeptember 30, 2020.


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Operating costs and expenses
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20202019Change20202019Change
Cost of sales$180 $302 $(122)$369 $541 $(172)
Cost of sales—affiliate16 2 14 24 2 22 
Cost of sales—related party29 23 6 77 59 18 
Operating and maintenance expense91 63 28 275 156 119 
Operating and maintenance expense—affiliate23 15 8 68 36 32 
Operating and maintenance expense—related party2 — 2 4 — 4 
Development expense— — — — 1 (1)
General and administrative expense1 2 (1)5 5 — 
General and administrative expense—affiliate5 4 1 15 7 8 
Depreciation and amortization expense86 67 19 256 146 110 
Impairment expense and loss on disposal of assets1 — 1 1 — 1 
Total operating costs and expenses$434 $478 $(44)$1,094 $953 $141 
 Three Months Ended June 30, Six Months Ended June 30,
(in millions)2020 2019 Change 2020 2019 Change
Cost of sales$140
 $180
 $(40) $189
 $239
 $(50)
Cost of sales—affiliate2
 —
 2
 8
 —
 8
Cost of sales—related party25
 26
 (1) 48
 36
 12
Operating and maintenance expense95
 61
 34
 184
 93
 91
Operating and maintenance expense—affiliate25
 16
 9
 45
 21
 24
Operating and maintenance expense—related party2
 —
 2
 2
 —
 2
Development expense—
 1
 (1) —
 1
 (1)
General and administrative expense2
 1
 1
 4
 3
 1
General and administrative expense—affiliate5
 2
 3
 10
 3
 7
Depreciation and amortization expense86
 57
 29
 170
 79
 91
Total operating costs and expenses$382

$344

$38
 $660

$475

$185

Our total operating costs and expenses increaseddecreased between the three and six months ended JuneSeptember 30, 2020 and 2019, primarily as a result of higher depreciationdecreased cost of sales from lower volumes and amortization expensea slight decrease in pricing of natural gas feedstock. Operating costs and expenses increased between the nine months ended September 30, 2020 and 2019, primarily as a result of an additional Train in operationoperating between the periods, increased depreciation and amortization expense and costs incurred in response to the COVID-19 pandemic, as further described earlier in Impact of COVID-19 and Market Environment, partially offset by decreased costs of sales.

Cost of sales (including affiliate and related party) decreased between the three and nine months ended JuneSeptember 30, 2020 from the three and nine months ended September 30, 2019 primarily due to decreased pricingas a result of natural gas feedstock, which was partially offset by increased volume related to our LNG sales and a decrease in the fair value of commodity derivatives to secure natural gas feedstock for the Liquefaction Project due to an unfavorable shift in long-term forward prices relative to our hedge position between the periods. Cost of sales (including affiliate and related party) decreased between the six months ended June 30, 2020 and 2019, primarily related to an increaseincreases in fair value of commodity derivatives to secure natural gas feedstock for the Liquefaction Project due to relative shiftsdue to a favorable shift in long-term forward prices relative to our hedged positionposition. Cost of sales (including affiliate and related party) also decreased during the three months ended September 30, 2020 due to a lower volumes and a slight decrease in pricing of natural gas feedstock, which was partially offset by increases in costs associated with sale of unutilized natural gas procured for the increaseliquefaction process and a portion of derivative instruments that settle through physical delivery. Decrease in cost of sales (including affiliate and related party) during the volumenine months ended September 30, 2020 was partially offset by increased cost of natural gas feedstock as a result of higher volume related to our LNG sales due to an additional Train in operation between the periods.periods, but lower pricing. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project, to the extent those costs are not utilized for the commissioning process.

Operating and maintenance expense (including affiliate and related party) primarily includes costs associated with operating and maintaining the Liquefaction Project. Additionally, operating and maintenance expense (including affiliate) includes costs incurred in response to the COVID-19 pandemic, as further described earlier in Impact of COVID-19 and Market Environment, which was the primary reason for the increase between the three months ended June 30, 2020 and 2019 and also contributed to the increase between the six months ended June 30, 2020 and 2019. Operating and maintenance expense (including affiliate) alsoaffiliate and related party) increased between the three and sixnine months ended JuneSeptember 30, 2020 and 2019 due to increased third-party service and maintenance contract costs, increased natural gas transportation and storage capacity demand charges and increased payroll and benefit costs of operations personnel, generally as a result of an additional Train in operation between the periods. Additionally, operating and maintenance expense (including affiliate) during the three and nine months ended September 30, 2020 includes costs incurred in response to the COVID-19 pandemic, as further described earlier in Impact of COVID-19 and Market Environment. Operating and maintenance (including affiliates) also includes insurance and regulatory costs and other operating costs.

Depreciation and amortization expense increased during the three and sixnine months ended JuneSeptember 30, 2020 from the comparable period in 2019 as a result of commencing operations of Trains 1 and 2 of the Liquefaction Project in February 2019 and August 2019, respectively.

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Other expense (income)
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20202019Change20202019Change
Interest expense, net of capitalized interest$89 $90 $(1)$278 $175 $103 
Loss on modification or extinguishment of debt9 14 (5)9 14 (5)
Interest rate derivative loss, net— 78 (78)233 187 46 
Other income, net(1)— (1)(1)(3)2 
Total other expense$97 $182 $(85)$519 $373 $146 
 Three Months Ended June 30, Six Months Ended June 30,
(in millions)2020 2019 Change 2020 2019 Change
Interest expense, net of capitalized interest$90
 $73
 $17
 $189
 $85
 $104
Interest rate derivative loss, net25
 74
 (49) 233
 109
 124
Other expense (income), net1
 (2) 3
 —
 (3) 3
Total other expense$116
 $145
 $(29) $422
 $191
 $231


Interest expense, net of capitalized interest increased between the three and sixnine months ended JuneSeptember 30, 2020 and 2019, primarily as a result of a decrease in the portion of total interest costs that is eligible for capitalization due to the commencement of operations at the Liquefaction Project, partially offset by lower interest costs as a result of refinancing a portion of the outstanding balance under the CCH Credit Facility and lower interest rates. We incurred $119$117 million and $138$137 million of total interest cost during the three months ended September 30, 2020 and 2019, respectively, of which we capitalized $29$28 million and $65$47 million, respectively, and we incurred $365 million and $408 million of total interest cost during the nine months ended September 30, 2020 and 2019, respectively, of which waswe capitalized $87 million and $233 million, respectively. Capitalized interest primarily related to interest costs incurred to construct the remaining assets of the Liquefaction ProjectProject.

Loss on modification or extinguishment of debt decreased during the three and nine months ended JuneSeptember 30, 2020 as compared to the three and nine months ended September 30, 2019. Loss on modification or extinguishment of debt during three and nine months ended September 30, 2020 and 2019 respectively. We incurred $248 million and $271 millionwas attributable to the prepayment of total interest cost, of which we capitalized $59 million and $186 million, which was primarily related to interest costs incurred to construct the remaining assetsa portion of the Liquefaction Project duringoutstanding balance of the six months ended June 30, 2020 and 2019, respectively.CCH Credit Facility using proceeds from the issuance of senior notes or as part of Cheniere’s capital allocation framework.

Interest rate derivative loss, net decreased during the three months ended JuneSeptember 30, 2020 compared to the three months ended JuneSeptember 30, 2019, primarily due to a favorable shift in the long-term forward LIBOR curve between the periods. Interest rate derivative loss, net increased during the sixnine months ended JuneSeptember 30, 2020 compared to the sixnine months ended JuneSeptember 30, 2019, primarily due to an unfavorable shift in the long-term forward LIBOR curve between the periods.

Off-Balance Sheet Arrangements
 
As of JuneSeptember 30, 2020, we had no transactions that met the definition of off-balance sheet arrangements that may have a current or future material effect on our consolidated financial position or operating results. 

Summary of Critical Accounting Estimates

The preparation of our 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, 2019.

Recent Accounting Standards 

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

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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 Liquefaction Project (“Liquefaction Supply Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location as follows (in millions):
September 30, 2020December 31, 2019
Fair ValueChange in Fair ValueFair ValueChange in Fair Value
Liquefaction Supply Derivatives$174 $62 $48 $63 
 June 30, 2020 December 31, 2019
 Fair Value Change in Fair Value Fair Value Change in Fair Value
Liquefaction Supply Derivatives$184
 $40
 $48
 $63


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. We have 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”) and to hedge against changes in interest rates that could impact our anticipated future issuance of debt (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”). In order to test the sensitivity of the fair value of the 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 and CCH Interest Rate Forward Start Derivatives as follows (in millions):
September 30, 2020December 31, 2019
Fair ValueChange in Fair ValueFair ValueChange in Fair Value
CCH Interest Rate Derivatives$(165)$1 $(81)$19 
CCH Interest Rate Forward Start Derivatives— — (8)15 
 June 30, 2020 December 31, 2019
 Fair Value Change in Fair Value Fair Value Change in Fair Value
CCH Interest Rate Derivatives$(191) $2
 $(81) $19
CCH Interest Rate Forward Start Derivatives(102) 7
 (8) 15

See Note 6—Derivative Instruments for additional details about our derivative instruments.

ITEM 4.CONTROLS AND PROCEDURES

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 voluntarily 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 President and Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our President and Chief Financial Officer concluded that our disclosure controls and procedures are effective.

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

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PART II.     OTHER INFORMATION

ITEM 1.LEGAL PROCEEDINGS
LEGAL PROCEEDINGS
 
We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. There have been no material changes to the legal proceedings disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2019.

ITEM 1A.RISK FACTORS
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, 2019, except for the updates presented in our quarterly report on Form 10-Q for the quarterly period ending March 31, 2020.

ITEM 6.     EXHIBITS
ITEM 6.EXHIBITS
Exhibit No.Description
10.1*Exhibit No.Description
4.1
Indenture, dated as of August 20, 2020, among the Company, as issuer, and CCL, CCP and CCP GP, as guarantors, and The Bank of New York Mellon, as trustee (Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K (SEC File No. 333-215435), filed on August 21, 2020)
10.1*
Change orders to the Amended and Restated Fixed Price Separated Turnkey Agreement for the Engineering, Procurement and Construction of the Corpus Christi Stage 2 Liquefaction Facility, dated as of December 12, 2017, between CCL and Bechtel Oil, Gas and Chemicals, Inc.: (i) the Change Order CO-00031 Tank B Isolation of Proposed 4th In-Tank LNG Pump (Post Start-Up of Tank B) - EPC,CO-00035 Spill Conveyance from Flare KO Drum Area, dated April 1,July 6, 2020, (ii) the Change Order CO-00032 Train 3 Thermowell Upgrades,CO-00036 Tie-Ins for Heavy Hydrocarbon Removal Modifications (E&P) Rev 1, dated April 3,August 5, 2020, (iii) the Change Order CO-00033 Tank B Rundown Line (Part 2) Development Costs,CO-00037 Train 3 PV-16002 Valve Trim Change - Rev 1, dated April 29,August 14, 2020, and (iv) the Change Order CO-00034 Train 3 UPS ModificationCO-00038 Hot Oil Overpressure Relief, dated August 14, 2020, (v) the Change Order CO-00039 Supply of MV Motors,Nitrogen for Commissioning Units 16, 17 and Feed Gas, dated May 21,August 20, 2020 and (vi) the Change Order CO-00040 COVID-19 Impacts, dated September 15, 2020 (Portions of this exhibit have been omitted)
22.1
List of Issuers and Guarantor Subsidiaries (Incorporated by reference to Exhibit 22.1 to the Company’s Registration Report on Form S-4 (SEC File No. 333-215435), filed on July 14, 2020)
31.1*
Certification by President and Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**
Certification by President and 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.

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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 CORPUS CHRISTI HOLDINGS, LLC
Date:November 5, 2020By:/s/ Zach Davis
Zach Davis
President and Chief Financial Officer
(Principal Executive and Financial Officer)
Date:CHENIERE CORPUS CHRISTI HOLDINGS, LLC
Date:AugustNovember 5, 2020By:/s/ Michael J. Wortley
Michael J. Wortley
President and Chief Financial Officer
(Principal Executive and Financial Officer)
Date:August 5, 2020By:/s/ Leonard E. Travis
Leonard E. Travis
Chief Accounting Officer
(on behalf of the registrant and
as principal accounting officer)


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