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Cheniere Energy, Inc. - Quarter Report: 2019 June (Form 10-Q)



 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
 
 
 
 
FORM 10-Q
 
 
 
 
 
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

  For the quarterly period ended June 30, 2019
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 001-16383
colorlogoonwhitecmyka39.gif
CHENIERE ENERGY, INC.
(Exact name of registrant as specified in its charter)
 
 
 
 
 
Delaware
95-4352386
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
 
 
 
 
700 Milam Street
,
Suite 1900
 
Houston
,
Texas
77002
(Address of principal executive offices)
(Zip Code)
(713375-5000
(Registrant’s telephone number, including area code)
 
 
 
 
 
Securities registered pursuant to Section 12(b) of the Act: 
Title of each class
Trading Symbol
Name of each exchange on which registered
Common Stock, $ 0.003 par value
LNG
NYSE American
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes    No 
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  Yes     No 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
 
Large accelerated filer
 
Accelerated filer
 
Non-accelerated filer
 
Smaller reporting company
 
 
 
 
Emerging growth company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes    No   
As of August 2, 2019, the issuer had 256,779,983 shares of Common Stock outstanding.
 



CHENIERE ENERGY, INC.
TABLE OF CONTENTS



 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


i


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

Common Industry and Other Terms
Bcf
 
billion cubic feet
Bcf/d
 
billion cubic feet per day
Bcf/yr
 
billion cubic feet per year
Bcfe
 
billion cubic feet equivalent
DOE
 
U.S. Department of Energy
EPC
 
engineering, procurement and construction
FERC
 
Federal Energy Regulatory Commission
FTA countries
 
countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAP
 
generally accepted accounting principles in the United States
Henry Hub
 
the final settlement price (in USD per MMBtu) for the New York Mercantile Exchange’s Henry Hub natural gas futures contract for the month in which a relevant cargo’s delivery window is scheduled to begin
LIBOR
 
London Interbank Offered Rate
LNG
 
liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state
MMBtu
 
million British thermal units, an energy unit
mtpa
 
million tonnes per annum
non-FTA countries
 
countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC
 
U.S. Securities and Exchange Commission
SPA
 
LNG sale and purchase agreement
TBtu
 
trillion British thermal units, an energy unit
Train
 
an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA
 
terminal use agreement


1


Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of June 30, 2019, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:
ceiorgchart63019.gif
Unless the context requires otherwise, references to “Cheniere,” the “Company,” “we,” “us” and “our” refer to Cheniere Energy, Inc. and its consolidated subsidiaries, including our publicly traded subsidiary, Cheniere Partners.
Unless the context requires otherwise, references to the “CCH Group” refer to CCH HoldCo II, CCH HoldCo I, CCH, CCL and CCP, collectively.

2




PART I.
FINANCIAL INFORMATION
ITEM 1.
CONSOLIDATED FINANCIAL STATEMENTS
CHENIERE ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(in millions, except share data)
 
June 30,
 
December 31,
 
2019
 
2018
ASSETS
(unaudited)
 
 
Current assets
 
 
 
Cash and cash equivalents
$
2,279

 
$
981

Restricted cash
1,161

 
2,175

Accounts and other receivables
433

 
585

Inventory
290

 
316

Derivative assets
127

 
63

Other current assets
135

 
114

Total current assets
4,425

 
4,234

 
 
 
 
Property, plant and equipment, net
29,073

 
27,245

Operating lease assets, net
502

 

Debt issuance costs, net
55

 
72

Non-current derivative assets
103

 
54

Goodwill
77

 
77

Other non-current assets, net
337

 
305

Total assets
$
34,572

 
$
31,987

 
 
 
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 

 
 

Current liabilities
 

 
 

Accounts payable
$
120

 
$
58

Accrued liabilities
1,572

 
1,169

Current debt

 
239

Deferred revenue
136

 
139

Current operating lease liabilities
292

 

Derivative liabilities
84

 
128

Other current liabilities
3

 
9

Total current liabilities
2,207

 
1,742

 
 
 
 
Long-term debt, net
29,944

 
28,179

Non-current operating lease liabilities
202

 

Non-current finance lease liabilities
58

 
57

Non-current derivative liabilities
94

 
22

Other non-current liabilities
44

 
58

 
 
 
 
Commitments and contingencies (see Note 16)


 


 
 
 
 
Stockholders’ equity
 

 
 

Preferred stock, $0.0001 par value, 5.0 million shares authorized, none issued

 

Common stock, $0.003 par value
 
 
 

Authorized: 480.0 million shares at June 30, 2019 and December 31, 2018
 
 
 
Issued: 270.5 million shares at June 30, 2019 and 269.8 million shares at December 31, 2018


 


Outstanding: 257.5 million shares at June 30, 2019 and 257.0 million shares at December 31, 2018
1

 
1

Treasury stock: 13.0 million shares and 12.8 million shares at June 30, 2019 and December 31, 2018, respectively, at cost
(423
)
 
(406
)
Additional paid-in-capital
4,097

 
4,035

Accumulated deficit
(4,129
)
 
(4,156
)
Total stockholders’ deficit
(454
)
 
(526
)
Non-controlling interest
2,477

 
2,455

Total equity
2,023

 
1,929

Total liabilities and equity
$
34,572

 
$
31,987


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

3



CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS
(in millions, except per share data) 
(unaudited)
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
2019
 
2018
 
2019
 
2018
Revenues
 
 
 
 
 
 
 
LNG revenues
$
2,173

 
$
1,442

 
$
4,316

 
$
3,608

Regasification revenues
67

 
65

 
133

 
130

Other revenues
52

 
36

 
104

 
47

Total revenues
2,292

 
1,543

 
4,553

 
3,785

 
 
 
 
 
 
 
 
Operating costs and expenses
 
 
 
 
 
 
 
Cost of sales (excluding depreciation and amortization expense shown separately below)
1,277

 
873

 
2,491

 
2,051

Operating and maintenance expense
295

 
147

 
516

 
287

Development expense
3

 
3

 
4

 
4

Selling, general and administrative expense
77

 
73

 
150

 
140

Depreciation and amortization expense
204

 
111

 
348

 
220

Impairment expense and loss on disposal of assets
4

 

 
6

 

Total operating costs and expenses
1,860

 
1,207

 
3,515

 
2,702

 
 
 
 
 
 
 
 
Income from operations
432

 
336

 
1,038

 
1,083

 
 
 
 
 
 
 
 
Other income (expense)
 
 
 
 
 
 
 
Interest expense, net of capitalized interest
(372
)
 
(216
)
 
(619
)
 
(432
)
Loss on modification or extinguishment of debt

 
(15
)
 

 
(15
)
Derivative gain (loss), net
(74
)
 
32

 
(109
)
 
109

Other income
16

 
10

 
32

 
17

Total other expense
(430
)
 
(189
)
 
(696
)
 
(321
)
 
 
 
 
 
 
 
 
Income before income taxes and non-controlling interest
2


147


342


762

Income tax benefit (provision)


3


(3
)

(12
)
Net income
2


150


339


750

Less: net income attributable to non-controlling interest
116


168


312


411

Net income (loss) attributable to common stockholders
$
(114
)

$
(18
)

$
27


$
339













Net income (loss) per share attributable to common stockholders—basic (1)
$
(0.44
)

$
(0.07
)

$
0.11


$
1.42

Net income (loss) per share attributable to common stockholders—diluted (1)
$
(0.44
)
 
$
(0.07
)
 
$
0.11

 
$
1.40

 











Weighted average number of common shares outstanding—basic
257.4

 
242.8

 
257.3

 
239.2

Weighted average number of common shares outstanding—diluted
257.4

 
242.8

 
258.6

 
241.7


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




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

4



CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(in millions)
(unaudited)
Three and Six Months Ended June 30, 2019
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total Stockholders’ Equity
 
 
 
 
Common Stock
 
Treasury Stock
 
Additional Paid-in Capital
 
Accumulated Deficit
 
Non-controlling Interest
 
Total
Equity
 
Shares
 
Par Value Amount
 
Shares
 
Amount
 
 
 
 
Balance at December 31, 2018
257.0


$
1


12.8


$
(406
)

$
4,035


$
(4,156
)

$
2,455


$
1,929

Vesting of restricted stock units
0.6

 

 

 

 

 

 

 

Share-based compensation

 

 

 

 
28

 

 

 
28

Shares withheld from employees related to share-based compensation, at cost
(0.2
)
 

 
0.2

 
(12
)
 

 

 

 
(12
)
Net income attributable to non-controlling interest

 

 

 

 

 

 
196

 
196

Distributions and dividends to non-controlling interest

 

 

 

 

 

 
(144
)
 
(144
)
Net income

 

 

 

 

 
141

 

 
141

Balance at March 31, 2019
257.4

 
1

 
13.0

 
(418
)
 
4,063

 
(4,015
)
 
2,507

 
2,138

Vesting of restricted stock units
0.1

 

 

 

 

 

 

 

Share-based compensation

 

 

 

 
33

 

 

 
33

Shares withheld from employees related to share-based compensation, at cost

 

 

 
(2
)
 

 

 

 
(2
)
Shares repurchased, at cost

 

 

 
(3
)
 

 

 

 
(3
)
Net income attributable to non-controlling interest

 

 

 

 

 

 
116

 
116

Equity portion of convertible notes, net

 

 

 

 
1

 

 

 
1

Distributions and dividends to non-controlling interest

 

 

 

 

 

 
(146
)
 
(146
)
Net loss

 

 

 

 

 
(114
)
 

 
(114
)
Balance at June 30, 2019
257.5

 
$
1

 
13.0

 
$
(423
)
 
$
4,097

 
$
(4,129
)
 
$
2,477

 
$
2,023










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

5



CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY—CONTINUED
(in millions)
(unaudited)
Three and Six Months Ended June 30, 2018
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total Stockholders’ Equity
 
 
 
 
Common Stock
 
Treasury Stock
 
Additional Paid-in Capital
 
Accumulated Deficit
 
Non-controlling Interest
 
Total
Equity
 
Shares
 
Par Value Amount
 
Shares
 
Amount
 
 
 
 
Balance at December 31, 2017
237.6

 
$
1

 
12.5

 
$
(386
)
 
$
3,248

 
$
(4,627
)
 
$
3,004

 
$
1,240

Vesting of restricted stock units
0.3

 

 

 

 

 

 

 

Share-based compensation

 

 

 

 
16

 

 

 
16

Shares withheld from employees related to share-based compensation, at cost

 

 
0.1

 
(6
)
 

 

 

 
(6
)
Net income attributable to non-controlling interest

 

 

 

 

 

 
243

 
243

Distributions and dividends to non-controlling interest

 

 

 

 

 

 
(143
)
 
(143
)
Net income

 

 

 

 

 
357

 

 
357

Balance at March 31, 2018
237.9

 
1

 
12.6

 
(392
)
 
3,264

 
(4,270
)
 
3,104

 
1,707

Issuance of stock to acquire additional interest in Cheniere Holdings
10.3

 

 

 

 
376

 

 
(376
)
 

Share-based compensation

 

 

 

 
23

 

 

 
23

Shares withheld from employees related to share-based compensation, at cost
(0.1
)
 

 

 
(2
)
 

 

 

 
(2
)
Net income attributable to non-controlling interest

 

 

 

 

 

 
168

 
168

Equity portion of convertible notes, net

 

 

 

 
1

 

 

 
1

Distributions and dividends to non-controlling interest

 

 

 

 

 

 
(145
)
 
(145
)
Net loss

 

 

 

 

 
(18
)
 

 
(18
)
Balance at June 30, 2018
248.1

 
$
1

 
12.6

 
$
(394
)
 
$
3,664

 
$
(4,288
)
 
$
2,751

 
$
1,734



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

6



CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS
(in millions)
(unaudited)
 
Six Months Ended June 30,
 
2019
 
2018
Cash flows from operating activities
 
 
 
Net income
$
339

 
$
750

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation and amortization expense
348

 
220

Share-based compensation expense
61

 
58

Non-cash interest expense
93

 
30

Amortization of debt issuance costs, deferred commitment fees, premium and discount
44

 
35

Amortization of operating lease assets
158

 

Loss on modification or extinguishment of debt

 
15

Total losses (gains) on derivatives, net
(147
)
 
4

Net cash provided by (used for) settlement of derivative instruments
62

 
(8
)
Impairment expense and loss on disposal of assets
6

 

Other
2

 
(5
)
Changes in operating assets and liabilities:
 
 
 
Accounts and other receivables
59

 
80

Inventory
33

 
10

Other current assets
(46
)
 
(61
)
Accounts payable and accrued liabilities
(80
)
 
(132
)
Deferred revenue
(2
)
 
(13
)
Operating lease liabilities
(163
)
 

Other, net
(7
)
 
(1
)
Net cash provided by operating activities
760

 
982

 
 
 
 
Cash flows from investing activities
 
 
 
Property, plant and equipment, net
(1,508
)
 
(1,508
)
Investment in equity method investment
(34
)
 

Other

 
16

Net cash used in investing activities
(1,542
)
 
(1,492
)
 
 
 
 
Cash flows from financing activities
 
 
 
Proceeds from issuances of debt
2,021

 
1,799

Repayments of debt
(630
)
 
(281
)
Debt issuance and deferred financing costs
(20
)
 
(46
)
Debt extinguishment costs

 
(8
)
Distributions and dividends to non-controlling interest
(290
)
 
(288
)
Payments related to tax withholdings for share-based compensation
(14
)
 
(8
)
Repurchase of common stock
(3
)
 

Other
2

 

Net cash provided by financing activities
1,066

 
1,168

 
 
 
 
Net increase in cash, cash equivalents and restricted cash
284

 
658

Cash, cash equivalents and restricted cash—beginning of period
3,156

 
2,613

Cash, cash equivalents and restricted cash—end of period
$
3,440

 
$
3,271

Balances per Consolidated Balance Sheet:
 
June 30, 2019
Cash and cash equivalents
$
2,279

Restricted cash
1,161

Total cash, cash equivalents and restricted cash
$
3,440


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

7


  
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)


NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We own and operate two natural gas liquefaction and export facilities at Sabine Pass and Corpus Christi. The Sabine Pass LNG terminal is located in Cameron Parish, Louisiana, on the Sabine-Neches Waterway less than four miles from the Gulf Coast. Cheniere Partners is in various stages of constructing and operating six natural gas liquefaction facilities (the “SPL Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, SPL. Trains 1 through 5 are operational and Train 6 is under construction. The Sabine Pass LNG terminal has operational regasification facilities owned by Cheniere Partners’ wholly owned subsidiary, SPLNG, and a 94-mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines owned by Cheniere Partners’ wholly owned subsidiary, CTPL.

The Corpus Christi LNG terminal is located near Corpus Christi, Texas and is operated by our wholly owned subsidiary CCL. We also operate 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 “CCL Project”) through our wholly owned subsidiary CCP. The CCL Project is being developed in stages with the first phase being three Trains (“Phase 1”). The first stage includes Trains 1 and 2, two LNG storage tanks, one complete marine berth and a second partial berth and all of the CCL Project’s necessary infrastructure facilities (“Stage 1”). The second stage includes Train 3, one LNG storage tank and the completion of the second partial berth (“Stage 2”). Train 1 is operational, Train 2 is undergoing commissioning and Train 3 is under construction.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) and filed an application with FERC in June 2018 for seven midscale Trains with an expected aggregate nominal production capacity of approximately 9.5 mtpa and one LNG storage tank.

We remain focused on expansion of our existing sites by leveraging existing infrastructure. We continue to consider development of other projects, including infrastructure projects in support of natural gas supply and LNG demand, which, among other things, will require acceptable commercial and financing arrangements before we make a final investment decision (“FID”).

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2018. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included.

Results of operations for the three and six months ended June 30, 2019 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2019.

Recent Accounting Standards

We adopted ASU 2016-02, Leases (Topic 842), and subsequent amendments thereto (“ASC 842”) on January 1, 2019 using the optional transition approach to apply the standard at the beginning of the first quarter of 2019 with no retrospective adjustments to prior periods. The adoption of the standard resulted in the recognition of right-of-use assets and lease liabilities for operating leases of approximately $550 million on our Consolidated Balance Sheets, with no material impact on our Consolidated Statements of Operations or Consolidated Statements of Cash Flows. We have elected the practical expedients to (1) carryforward prior conclusions related to lease identification and classification for existing leases, (2) combine lease and non-lease components of an arrangement for all classes of leased assets, (3) omit short-term leases with a term of 12 months or less from recognition on the balance sheet and (4) carryforward our existing accounting for land easements not previously accounted for as leases. See Note 11—Leases for additional information on our leases following the adoption of this standard.


8


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 2—RESTRICTED CASH
 
Restricted cash consists of funds that are contractually and legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. As of June 30, 2019 and December 31, 2018, restricted cash consisted of the following (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Current restricted cash
 
 
 
 
SPL Project
 
$
596

 
$
756

Cheniere Partners and cash held by guarantor subsidiaries
 

 
785

CCL Project
 
279

 
289

Cash held by our subsidiaries restricted to Cheniere
 
286

 
345

Total current restricted cash
 
$
1,161

 
$
2,175



Pursuant to the accounts agreements entered into with the collateral trustees for the benefit of SPL’s debt holders and CCH’s debt holders, SPL and CCH are required to deposit all cash received into reserve accounts controlled by the collateral trustees.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) and other restricted payments.

In May 2019, Cheniere Partners entered into the $1.5 billion credit facilities (the “2019 CQP Credit Facilities”), which replaced the previous $2.8 billion credit facilities (the “2016 CQP Credit Facilities”). The cash held by Cheniere Partners and its guarantor subsidiaries was restricted in use under the terms of the 2016 CQP Credit Facilities and the related depositary agreement governing the extension of credit to Cheniere Partners, but is no longer restricted under the 2019 CQP Credit Facilities.

NOTE 3—ACCOUNTS AND OTHER RECEIVABLES

As of June 30, 2019 and December 31, 2018, accounts and other receivables consisted of the following (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Trade receivables
 
 
 
 
SPL and CCL
 
$
257

 
$
330

Cheniere Marketing
 
145

 
205

Other accounts receivable
 
31

 
50

Total accounts and other receivables
 
$
433

 
$
585



NOTE 4—INVENTORY

As of June 30, 2019 and December 31, 2018, inventory consisted of the following (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Natural gas
 
$
19

 
$
30

LNG
 
38

 
24

LNG in-transit
 
104

 
173

Materials and other
 
129

 
89

Total inventory
 
$
290

 
$
316




9


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 5—PROPERTY, PLANT AND EQUIPMENT
 
As of June 30, 2019 and December 31, 2018, property, plant and equipment, net consisted of the following (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
LNG terminal costs
 
 
 
 
LNG terminal and interconnecting pipeline facilities
 
$
23,650

 
$
13,386

LNG site and related costs
 
319

 
86

LNG terminal construction-in-process
 
6,529

 
14,864

Accumulated depreciation
 
(1,625
)
 
(1,299
)
Total LNG terminal costs, net
 
28,873

 
27,037

Fixed assets and other
 
 

 
 

Computer and office equipment
 
22

 
17

Furniture and fixtures
 
22

 
22

Computer software
 
104

 
100

Leasehold improvements
 
42

 
41

Land
 
59

 
59

Other
 
20

 
21

Accumulated depreciation
 
(127
)
 
(111
)
Total fixed assets and other, net
 
142

 
149

Assets under finance lease
 
 
 
 
Tug vessels
 
60

 
60

Accumulated depreciation
 
(2
)
 
(1
)
Total assets under finance lease, net
 
58

 
59

Property, plant and equipment, net
 
$
29,073

 
$
27,245



Depreciation expense was $203 million and $111 million during the three months ended June 30, 2019 and 2018, respectively, and $346 million and $219 million during the six months ended June 30, 2019 and 2018, respectively.

We realize offsets to LNG terminal costs for sales of commissioning cargoes that were earned or loaded prior to the start of commercial operations of the respective Train during the testing phase for its construction. We realized offsets to LNG terminal costs of $202 million during the six months ended June 30, 2019 for sales of commissioning cargoes from the Liquefaction Projects. We did not realize any offsets to LNG terminal costs during the three months ended June 30, 2019 and the three and six months ended June 30, 2018.

NOTE 6—DERIVATIVE INSTRUMENTS
 
We have entered into the following derivative instruments that are reported at fair value:
interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under CCH’s credit facilities (“CCH Interest Rate Derivatives”) and to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH (“CCH Interest Rate Forward Start Derivatives”);
commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the SPL Project, CCL Project and potential future development of Corpus Christi Stage 3 (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (collectively, the “Liquefaction Supply Derivatives”);
financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (“LNG Trading Derivatives”); and
foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with both LNG Trading Derivatives and operations in countries outside of the United States (“FX Derivatives”).
We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process.

10


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of June 30, 2019 and December 31, 2018, which are classified as derivative assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in millions):
 
Fair Value Measurements as of
 
June 30, 2019
 
December 31, 2018
 
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 asset (liability)
$

 
$
(88
)
 
$

 
$
(88
)
 
$

 
$
18

 
$

 
$
18

CCH Interest Rate Forward Start Derivatives liability

 
(7
)
 

 
(7
)
 

 

 

 

Liquefaction Supply Derivatives asset (liability)

 
1

 
89

 
90

 
6

 
(19
)
 
(29
)
 
(42
)
LNG Trading Derivatives asset (liability)
(4
)
 
51

 

 
47

 
1

 
(25
)
 

 
(24
)
FX Derivatives asset

 
10

 

 
10

 

 
15

 

 
15



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

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 conditions precedent, 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 June 30, 2019 and December 31, 2018, 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. In determining and recording fair value, we do not use third party sources that derive price based on proprietary models or market surveys.

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 June 30, 2019:
 
 
Net Fair Value Asset (Liability)
(in millions)
 
Valuation Approach
 
Significant Unobservable Input
 
Significant Unobservable Inputs Range
Physical Liquefaction Supply Derivatives
 
$89
 
Market approach incorporating present value techniques
 
Henry Hub Basis Spread
 
$(0.700) - $0.056
 
 
 
 
Option pricing model
 
International pricing spread, relative to Henry Hub (1)
 
128% - 176%

 
(1)    Spread contemplates U.S. dollar-denominated pricing.


11


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

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 during the three and six months ended June 30, 2019 and 2018 (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
Balance, beginning of period
 
$
31

 
$
10

 
$
(29
)
 
$
43

Realized and mark-to-market gains (losses):
 
 
 
 
 
 
 
 
Included in cost of sales
 
7

 
(1
)
 
23

 
(12
)
Purchases and settlements:
 
 
 
 
 
 
 
 
Purchases
 
50

 
6

 
50

 
6

Settlements
 
1

 
(4
)
 
45

 
(25
)
Transfers out of Level 3 (1)
 

 
1

 

 

Balance, end of period
 
$
89

 
$
12

 
$
89

 
$
12

Change in unrealized gains (losses) relating to instruments still held at end of period
 
$
7

 
$
(1
)
 
$
23

 
$
(12
)
 
(1)    Transferred to Level 2 as a result of observable market for the underlying natural gas purchase agreements.

Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for 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 netting and any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

Interest Rate Derivatives

During the six months ended June 30, 2019, there were no changes to the terms of the CCH Interest Rate Derivatives entered into by CCH to protect against volatility of future cash flows and hedge a portion of the variable interest payments on its credit facility (the “CCH Credit Facility”).

In June 2019, we entered into the CCH Interest Rate Forward Start Derivatives to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH, which is anticipated by the end of 2020.

Cheniere Partners previously had interest rate swaps (“CQP Interest Rate Derivatives” and, collectively with the CCH Interest Rate Derivatives and the CCH Interest Rate Forward Start Derivatives, the “Interest Rate Derivatives”) to hedge a portion of the variable interest payments on its credit facilities, which were terminated in October 2018.

As of June 30, 2019, we had the following Interest Rate Derivatives outstanding:
 
 
Initial Notional Amount
 
Maximum Notional Amount
 
Effective Date
 
Maturity Date
 
Weighted Average Fixed Interest Rate Paid
 
Variable Interest Rate Received
CCH Interest Rate Derivatives
 
$29 million
 
$4.7 billion
 
May 20, 2015
 
May 31, 2022
 
2.30%
 
One-month LIBOR
CCH Interest Rate Forward Start Derivatives
 
$1.0 billion
 
$1.0 billion
 
June 30, 2020
 
September 30, 2030
 
2.11%
 
Three-month LIBOR



12


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the fair value and location of the Interest Rate Derivatives on our Consolidated Balance Sheets (in millions):
 
June 30, 2019
 
December 31, 2018
 
CCH Interest Rate Derivatives
 
CCH Interest Rate Forward Start Derivatives
 
Total
 
CCH Interest Rate Derivatives
 
CCH Interest Rate Forward Start Derivatives
 
Total
Consolidated Balance Sheet Location
 
 
 
 
 
 
 
 
 
 
 
Derivative assets
$

 
$

 
$

 
$
10

 
$

 
$
10

Non-current derivative assets

 

 

 
8

 

 
8

Total derivative assets






18




18

 
 
 
 
 


 
 
 
 
 


Derivative liabilities
(21
)
 

 
(21
)
 

 

 

Non-current derivative liabilities
(67
)
 
(7
)
 
(74
)
 

 

 

Total derivative liabilities
(88
)

(7
)

(95
)






 
 
 
 
 


 
 
 
 
 


Derivative asset (liability), net
$
(88
)

$
(7
)

$
(95
)

$
18


$


$
18


The following table shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and six months ended June 30, 2019 and 2018 (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
CCH Interest Rate Derivatives gain (loss)
 
$
(67
)
 
$
29

 
$
(102
)
 
$
98

CCH Interest Rate Forward Start Derivatives loss
 
(7
)
 

 
(7
)
 

CQP Interest Rate Derivatives gain
 

 
3

 

 
11



Commodity Derivatives

SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the SPL Project, the CCL Project and potential future development of Corpus Christi Stage 3, respectively, which are primarily indexed to the natural gas market and international LNG indices. The terms of the index-based physical natural gas supply contracts range up to approximately 15 years, some of which commence upon the satisfaction of certain conditions precedent.

We have entered into, and may from time to time enter into, financial LNG Trading Derivatives in the form of swaps, forwards, options or futures to economically hedge exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG. We have entered into LNG Trading Derivatives to secure a fixed price position to minimize future cash flow variability associated with LNG purchase and sale transactions.


13


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the fair value and location of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”) on our Consolidated Balance Sheets (in millions, except notional amount):
 
June 30, 2019
 
December 31, 2018
 
Liquefaction Supply Derivatives (1)
 
LNG Trading Derivatives (2)
 
Total
 
Liquefaction Supply Derivatives (1)
 
LNG Trading Derivatives (2)
 
Total
Consolidated Balance Sheet Location
 
 
 
 
 
 
 
 
 
 
 
Derivative assets
$
24

 
$
92

 
$
116

 
$
13

 
$
24

 
$
37

Non-current derivative assets
94

 
9

 
103

 
46

 

 
46

Total derivative assets
118

 
101

 
219

 
59

 
24

 
83

 
 
 
 
 
 
 
 
 
 
 
 
Derivative liabilities
(13
)
 
(50
)
 
(63
)
 
(79
)
 
(48
)
 
(127
)
Non-current derivative liabilities
(15
)
 
(4
)
 
(19
)
 
(22
)
 

 
(22
)
Total derivative liabilities
(28
)
 
(54
)
 
(82
)
 
(101
)
 
(48
)
 
(149
)
 
 
 
 
 
 
 
 
 
 
 
 
Derivative asset (liability), net
$
90

 
$
47

 
$
137

 
$
(42
)
 
$
(24
)
 
$
(66
)
 
 
 
 
 
 
 
 
 
 
 
 
Notional amount, net (in TBtu) (3)
6,781

 
50

 
 
 
5,832

 
12

 
 

 
    
(1)
Does not include collateral calls of $6 million and $5 million for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of June 30, 2019 and December 31, 2018, respectively. Includes derivative assets of $2 million and $2 million and non-current assets of $1 million and $3 million as of June 30, 2019 and December 31, 2018, respectively, for a natural gas supply contract CCL has with a related party.
(2)
Does not include collateral of $15 million and $9 million deposited for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of June 30, 2019 and December 31, 2018, respectively.
(3)
SPL had secured up to approximately 3,437 TBtu and 3,464 TBtu as of June 30, 2019 and December 31, 2018, respectively. CCL had secured up to approximately 2,787 TBtu and 2,801 TBtu of natural gas feedstock through natural gas supply contracts as of June 30, 2019 and December 31, 2018, respectively, of which 57 TBtu and 55 TBtu, respectively, were for a natural gas supply contract CCL has with a related party. Corpus Christi Stage 3 had secured up to approximately 754 TBtu of natural gas feedstock through natural gas supply contracts as of June 30, 2019.

The following table shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and six months ended June 30, 2019 and 2018 (in millions):
 
Consolidated Statements of Operations Location (1)
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
LNG Trading Derivatives gain (loss)
LNG revenues
 
$
94

 
$
(76
)
 
$
158

 
$
(70
)
LNG Trading Derivatives loss
Cost of sales
 
(51
)
 

 
(51
)
 

Liquefaction Supply Derivatives gain (loss) (2)
LNG revenues
 
(1
)
 

 
1

 

Liquefaction Supply Derivatives gain (loss) (2)(3)
Cost of sales
 
57

 
(3
)
 
139

 
(53
)
 
(1)
Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.
(2)
Does not include the realized value associated with derivative instruments that settle through physical delivery.
(3)
Includes $24 million and $36 million that CCL recorded in cost of sales under a natural gas supply contract with a related party during the three and six months ended June 30, 2019, respectively. Of this amount, $4 million was included in accrued liabilities as of June 30, 2019. CCL did not have any transactions during the three and six months ended June 30, 2018 under this contract.


14


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

FX Derivatives

The following table shows the fair value and location of our FX Derivatives on our Consolidated Balance Sheets (in millions):
 
 
 
Fair Value Measurements as of
 
Consolidated Balance Sheet Location
 
June 30, 2019
 
December 31, 2018
FX Derivatives
Derivative assets
 
$
11

 
$
16

FX Derivatives
Derivative liabilities
 

 
(1
)
FX Derivatives
Non-current derivative liabilities
 
(1
)
 



The total notional amount of our FX Derivatives was $942 million and $379 million as of June 30, 2019 and December 31, 2018, respectively.
    
The following table shows the changes in the fair value, settlements and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the three and six months ended June 30, 2019 and 2018 (in millions):
 
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
Consolidated Statements of Operations Location
 
2019
 
2018
 
2019
 
2018
FX Derivatives gain
LNG revenues
 
$

 
$
12

 
$
9

 
$
10



Consolidated Balance Sheet Presentation

Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions):
 
 
Gross Amounts Recognized
 
Gross Amounts Offset in the Consolidated Balance Sheets
 
Net Amounts Presented in the Consolidated Balance Sheets
Offsetting Derivative Assets (Liabilities)
 
 
 
As of June 30, 2019
 
 
 
 
 
 
CCH Interest Rate Derivatives
 
$
(88
)
 
$

 
$
(88
)
CCH Interest Rate Forward Start Derivatives
 
(7
)
 

 
(7
)
Liquefaction Supply Derivatives
 
121

 
(3
)
 
118

Liquefaction Supply Derivatives
 
(35
)
 
7

 
(28
)
LNG Trading Derivatives
 
109

 
(8
)
 
101

LNG Trading Derivatives
 
(62
)
 
8

 
(54
)
FX Derivatives
 
21

 
(10
)
 
11

FX Derivatives
 
(11
)
 
10

 
(1
)
As of December 31, 2018
 
 
 
 
 


CCH Interest Rate Derivatives
 
$
19

 
$
(1
)
 
$
18

Liquefaction Supply Derivatives
 
95

 
(36
)
 
59

Liquefaction Supply Derivatives
 
(121
)
 
20

 
(101
)
LNG Trading Derivatives
 
112

 
(88
)
 
24

LNG Trading Derivatives
 
(92
)
 
44

 
(48
)
FX Derivatives
 
30

 
(14
)
 
16

FX Derivatives
 
(2
)
 
1

 
(1
)



15


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 7—OTHER NON-CURRENT ASSETS

As of June 30, 2019 and December 31, 2018, other non-current assets, net consisted of the following (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Advances made to municipalities for water system enhancements
 
$
89

 
$
90

Advances and other asset conveyances to third parties to support LNG terminals
 
55

 
54

Tax-related payments and receivables
 
21

 
21

Equity method investments
 
124

 
94

Advances made under EPC and non-EPC contracts
 
11

 
14

Other
 
37

 
32

Total other non-current assets, net
 
$
337

 
$
305



Equity Method Investments

Our equity method investments consist of interests in privately-held companies. In 2017, we acquired an equity interest in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“Midship Pipeline”). Midship Pipeline is currently constructing an approximately 200-mile natural gas pipeline project (the “Midship Project”) that connects production in the Anadarko Basin to Gulf Coast markets. Construction of the Midship Project commenced in the first quarter of 2019.

Subsequent to Midship Project obtaining its financing in the form of credit facilities, in conjunction with existing equity, Midship Holdings is able to finance its current activities without additional subordinated financial support. As a result of the total equity investment at risk being sufficient to finance its activities, Midship Holdings is no longer a variable interest entity. We continue to report Midship Holdings as an equity method investment due to our ability to exercise significant influence over the operating and financial policies of Midship Holdings through our non-controlling voting rights on its board of managers. Our investment in Midship Holdings was $117 million and $85 million at June 30, 2019 and December 31, 2018, respectively.

Cheniere LNG O&M Services, LLC (“O&M Services”), our wholly owned subsidiary, provides the development, construction, operation and maintenance services associated with the Midship Project pursuant to agreements in which O&M Services receives an agreed upon fee and reimbursement of costs incurred. O&M Services recorded $3 million in each of the three months ended June 30, 2019 and 2018 and $7 million and $4 million in the six months ended June 30, 2019 and 2018, respectively, of other revenues and $2 million and $4 million of accounts receivable as of June 30, 2019 and December 31, 2018, respectively, for services provided to Midship Pipeline under these agreements. CCL has entered into a transportation precedent agreement and a negotiated rate agreement with Midship Pipeline to secure firm pipeline transportation capacity for a period of 10 years following commencement of the Midship Project. In May 2018, CCL issued a letter of credit to Midship Pipeline for drawings up to an aggregate maximum amount of $16 million. Midship Pipeline had not made any drawings on this letter of credit as of June 30, 2019.

NOTE 8—NON-CONTROLLING INTEREST

We own a 48.6% limited partner interest in Cheniere Partners in the form of 104.5 million common units and 135.4 million subordinated units, with the remaining non-controlling interest held by Blackstone CQP Holdco LP and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. Cheniere Partners is accounted for as a variable interest entity. See Note 10—Variable Interest Entities of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, 2018 for further information.


16


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 9—ACCRUED LIABILITIES
  
As of June 30, 2019 and December 31, 2018, accrued liabilities consisted of the following (in millions): 
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Interest costs and related debt fees
 
$
405

 
$
233

Accrued natural gas purchases
 
402

 
610

LNG terminals and related pipeline costs
 
630

 
125

Compensation and benefits
 
58

 
117

Accrued LNG inventory
 
3

 
14

Other accrued liabilities
 
74

 
70

Total accrued liabilities
 
$
1,572

 
$
1,169


 

17


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 10—DEBT
 
As of June 30, 2019 and December 31, 2018, our debt consisted of the following (in millions): 
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Long-term debt:
 
 
 
 
SPL
 
 
 


5.625% Senior Secured Notes due 2021 (“2021 SPL Senior Notes”)
 
$
2,000

 
$
2,000

6.25% Senior Secured Notes due 2022 (“2022 SPL Senior Notes”)
 
1,000

 
1,000

5.625% Senior Secured Notes due 2023 (“2023 SPL Senior Notes”)
 
1,500

 
1,500

5.75% Senior Secured Notes due 2024 (“2024 SPL Senior Notes”)
 
2,000

 
2,000

5.625% Senior Secured Notes due 2025 (“2025 SPL Senior Notes”)
 
2,000

 
2,000

5.875% Senior Secured Notes due 2026 (“2026 SPL Senior Notes”)
 
1,500

 
1,500

5.00% Senior Secured Notes due 2027 (“2027 SPL Senior Notes”)
 
1,500

 
1,500

4.200% Senior Secured Notes due 2028 (“2028 SPL Senior Notes”)
 
1,350

 
1,350

5.00% Senior Secured Notes due 2037 (“2037 SPL Senior Notes”)
 
800

 
800

Cheniere Partners
 
 
 
 
5.250% Senior Notes due 2025 (“2025 CQP Senior Notes”)
 
1,500

 
1,500

5.625% Senior Notes due 2026 (“2026 CQP Senior Notes”)
 
1,100

 
1,100

2016 CQP Credit Facilities
 

 

2019 CQP Credit Facilities
 
649

 

CCH
 
 
 
 
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

CCH Credit Facility
 
6,138

 
5,156

CCH HoldCo II
 
 
 
 
11.0% Convertible Senior Secured Notes due 2025 (“2025 CCH HoldCo II Convertible Senior Notes”)
 
1,536

 
1,455

Cheniere
 
 
 
 
4.875% Convertible Unsecured Notes due 2021 (“2021 Cheniere Convertible Unsecured Notes”)
 
1,248

 
1,218

4.25% Convertible Senior Notes due 2045 (“2045 Cheniere Convertible Senior Notes”)
 
625

 
625

$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”)
 

 

Unamortized premium, discount and debt issuance costs, net
 
(752
)
 
(775
)
Total long-term debt, net
 
29,944

 
28,179

 
 
 
 
 
Current debt:
 
 
 
 
$1.2 billion SPL Working Capital Facility (“SPL Working Capital Facility”)
 

 

$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)
 

 
168

Cheniere Marketing trade finance facilities
 

 
71

Total current debt
 

 
239

 
 
 
 
 
Total debt, net
 
$
29,944

 
$
28,418



2019 Debt Issuances and Terminations

2016 CQP Credit Facilities

In May 2019, the remaining commitments under the 2016 CQP Credit Facilities were terminated.  There were no write-offs of debt issuance costs associated with the termination of the 2016 CQP Credit Facilities.


18


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

2019 CQP Credit Facilities

In May 2019, Cheniere Partners entered into the $1.5 billion 2019 CQP Credit Facilities, which consist of a $750 million term loan (“CQP Term Facility”) and a $750 million revolving credit facility (“CQP Revolving Facility”). Borrowings under the 2019 CQP Credit Facilities will be used to fund the development and construction of Train 6 of the SPL Project and subject to a sublimit, for general corporate purposes. The CQP Revolving Facility is also available for the issuance of letters of credit.

Loans under the 2019 CQP Credit Facilities will accrue interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the prime rate, the federal funds effective rate, as published by the Federal Reserve Bank of New York, plus 0.50%, and the adjusted one-month LIBOR plus 1.0%), plus the applicable margin. Under the CQP Term Facility, the applicable margin for LIBOR loans is 1.50% per annum, and the applicable margin for base rate loans is 0.50% per annum, in each case with a 0.25% step-up beginning on May 29, 2022. Under the CQP Revolving Facility, the applicable margin for LIBOR loans is 1.25% to 2.125% per annum, and the applicable margin for base rate loans is 0.25% to 1.125% per annum, in each case depending on the then-current rating of Cheniere Partners. Interest on LIBOR loans is due and payable at the end of each applicable LIBOR period (and at the end of every three-month period within the LIBOR period, if any), and interest on base rate loans is due and payable at the end of each calendar quarter.

Cheniere Partners incurred $20 million of discounts and debt issuance costs in conjunction with the entry into the 2019 CQP Credit Facilities. Cheniere Partners pays a commitment fee equal to an annual rate of 30% of the margin for LIBOR loans multiplied by the average daily amount of the undrawn commitment, payable quarterly in arrears.

The 2019 CQP Credit Facilities mature on May 29, 2024. The principal of any loans under the 2019 CQP Credit Facilities must be repaid in quarterly installments commencing on May 29, 2023 based on an amortization schedule. Any outstanding balance may be repaid, in whole or in part, at any time without premium or penalty, except for interest hedging and interest rate breakage costs. The 2019 CQP Credit Facilities contain conditions precedent for extensions of credit, as well as customary affirmative and negative covenants, and limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions are satisfied.

The 2019 CQP Credit Facilities are unconditionally guaranteed by each subsidiary of Cheniere Partners other than SPL, Sabine Pass LNG-LP, LLC and certain subsidiaries of Cheniere Partners owning other development projects, as well as certain other specified subsidiaries and members of the foregoing entities.

Credit Facilities

Below is a summary of our credit facilities outstanding as of June 30, 2019 (in millions):
 
 
SPL Working Capital Facility (1)
 
2019 CQP Credit Facilities
 
CCH Credit Facility
 
CCH Working Capital Facility
 
Cheniere Revolving Credit Facility
Original facility size
 
$
1,200

 
$
1,500

 
$
8,404

 
$
350

 
$
750

Incremental commitments
 

 

 
1,566

 
850

 
500

Less:
 
 
 
 
 
 
 
 
 
 
Outstanding balance
 

 
649

 
6,138

 

 

Commitments prepaid or terminated
 

 

 
3,832

 

 

Letters of credit issued
 
415

 

 

 
338

 

Available commitment
 
$
785


$
851

 
$


$
862


$
1,250

 
 
 
 
 
 
 
 
 
 
 
Interest rate on outstanding balance
 
LIBOR plus 1.75% or base rate plus 0.75%
 
(2)
 
LIBOR plus 1.75% or base rate plus 0.75%
 
LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%
 
LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Weighted average interest rate of outstanding balance
 
n/a
 
3.92%
 
4.15%
 
n/a
 
n/a
Maturity date
 
December 31, 2020
 
May 29, 2024
 
June 30, 2024
 
June 29, 2023
 
December 23, 2022

 
(1)
The SPL Working Capital Facility was amended in May 2019 in connection with commercialization and financing of Train 6 of the SPL Project. All terms of the SPL Working Capital Facility substantially remained unchanged.

19


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

(2)
LIBOR plus 1.50% or base rate plus 0.50%, with a 0.25% step-up beginning on May 29, 2022 for the CQP Term Facility. LIBOR plus 1.25% to 2.125% or base rate plus 0.25% to 1.125%, depending on the then-current rating of Cheniere Partners for the CQP Revolving Facility.

Convertible Notes

Below is a summary of our convertible notes outstanding as of June 30, 2019 (in millions):
 
 
2021 Cheniere Convertible Unsecured Notes
 
2025 CCH HoldCo II Convertible Senior Notes
 
2045 Cheniere Convertible Senior Notes
Aggregate original principal
 
$
1,000

 
$
1,000

 
$
625

Debt component, net of discount and debt issuance costs
 
$
1,172

 
$
1,519

 
$
311

Equity component
 
$
210

 
$

 
$
194

Interest payment method
 
Paid-in-kind

 
Paid-in-kind (1)

 
Cash

Conversion by us (2)
 

 
(3)

 
(4)

Conversion by holders (2)
 
(5)

 
(6)

 
(7)

Conversion basis
 
Cash and/or stock

 
Stock

 
Cash and/or stock

Conversion value in excess of principal
 
$

 
$

 
$

Maturity date
 
May 28, 2021

 
May 13, 2025

 
March 15, 2045

Contractual interest rate
 
4.875
%
 
11.0
%
 
4.25
%
Effective interest rate (8)
 
8.4
%
 
11.9
%
 
9.4
%
Remaining debt discount and debt issuance costs amortization period (9)
 
1.9 years

 
1.3 years

 
25.7 years

 

(1)
Prior to the substantial completion of Train 2 of the CCL Project, interest will be paid entirely in kind. Following this date, the interest generally must be paid in cash; however, a portion of the interest may be paid in kind under certain specified circumstances.
(2)
Conversion is subject to various limitations and conditions.
(3)
Convertible on or after the later of March 1, 2020 and the substantial completion of Train 2 of the CCL Project, provided that our market capitalization is not less than $10.0 billion (“Eligible Conversion Date”). The conversion price is the lower of (1) a 10% discount to the average of the daily volume-weighted average price (“VWAP”) of our common stock for the 90 trading day period prior to the date notice is provided, and (2) a 10% discount to the closing price of our common stock on the trading day preceding the date notice is provided.
(4)
Redeemable at any time after March 15, 2020 at a redemption price payable in cash equal to the accreted amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date.
(5)
Initially convertible at $93.64 (subject to adjustment upon the occurrence of certain specified events), provided that the closing price of our common stock is greater than or equal to the conversion price on the conversion date.
(6)
Convertible on or after the six-month anniversary of the Eligible Conversion Date, provided that our total market capitalization is not less than $10.0 billion, at a price equal to the average of the daily VWAP of our common stock for the 90 trading day period prior to the date on which notice of conversion is provided.
(7)
Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes, which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).
(8)
Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

20


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

(9)
We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity except for the 2025 CCH HoldCo II Convertible Senior Notes, which are amortized through the date they are first convertible by holders into our common stock.

Restrictive Debt Covenants

As of June 30, 2019, each of our issuers was in compliance with all covenants related to their respective debt agreements.

Interest Expense

Total interest expense, including interest expense related to our convertible notes, consisted of the following (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
Interest cost on convertible notes:
 
 
 
 
 
 
 
 
Interest per contractual rate
 
$
64

 
$
58

 
$
126

 
$
116

Amortization of debt discount
 
9

 
8

 
19

 
16

Amortization of debt issuance costs
 
3

 
2

 
6

 
4

Total interest cost related to convertible notes
 
76

 
68

 
151

 
136

Interest cost on debt and finance leases excluding convertible notes
 
382

 
344

 
755


680

Total interest cost
 
458

 
412

 
906

 
816

Capitalized interest
 
(86
)
 
(196
)
 
(287
)
 
(384
)
Total interest expense, net
 
$
372


$
216

 
$
619

 
$
432



Fair Value Disclosures

The following table shows the carrying amount, which is net of unamortized premium, discount and debt issuance costs, and estimated fair value of our debt (in millions):
 
 
June 30, 2019
 
December 31, 2018
 
 
Carrying
Amount
 
Estimated
Fair Value
 
Carrying
Amount
 
Estimated
Fair Value
Senior notes (1)
 
$
19,483

 
$
21,499

 
$
19,466

 
$
19,901

2037 SPL Senior Notes (2)
 
791

 
912

 
791

 
817

Credit facilities (3)
 
6,668

 
6,668

 
5,294

 
5,294

2021 Cheniere Convertible Unsecured Notes (2)
 
1,172

 
1,302

 
1,126

 
1,236

2025 CCH HoldCo II Convertible Senior Notes (2)
 
1,519

 
1,771

 
1,432

 
1,612

2045 Cheniere Convertible Senior Notes (4)
 
311

 
489

 
310

 
431

 
(1)
Includes 2021 SPL Senior Notes, 2022 SPL Senior Notes, 2023 SPL Senior Notes, 2024 SPL Senior Notes, 2025 SPL Senior Notes, 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes, 2025 CQP Senior Notes, 2026 CQP Senior Notes, 2024 CCH Senior Notes, 2025 CCH Senior Notes and 2027 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 our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 
(3)
Includes SPL Working Capital Facility, 2016 CQP Credit Facilities, 2019 CQP Credit Facilities, CCH Credit Facility, CCH Working Capital Facility, Cheniere Revolving Credit Facility and Cheniere Marketing trade finance facilities. The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty. 
(4)
The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.


21


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 11—LEASES

Our leased assets consist primarily of (1) LNG vessel time charters (“vessel charters”), (2) tug vessels, (3) office space and facilities and (4) land sites, all of which are classified as operating leases except for our tug vessels at the Corpus Christi LNG terminal, which are classified as finance leases.

ASC 842 requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. As our leases generally do not provide an implicit rate, in order to calculate the lease liability, we discounted our expected future lease payments using our relevant subsidiary’s incremental borrowing rate at the later of January 1, 2019 or the commencement date of the lease. The incremental borrowing rate is an estimate of the rate of interest that a given subsidiary would have to pay to borrow on a collateralized basis over a similar term to that of the lease term.

Many of our leases contain renewal options exercisable at our sole discretion. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability only to the extent they are reasonably certain to be exercised, such as when necessary to satisfy obligations that existed at the execution of the lease or when the non-renewal would otherwise result in an economic penalty.

We have elected the practical expedient to omit leases with an initial term of 12 months or less (“short-term lease”) from recognition on the balance sheet. We recognize short-term lease payments on a straight-line basis over the lease term and variable payments under short-term leases in the period in which the obligation is incurred.

Certain of our leases contain non-lease components which are not separated from the lease components when calculating the right-of-use asset and lease liability per our use of the practical expedient to combine both components of an arrangement for all classes of leased assets.

Certain of our leases also contain variable payments, such as inflation, that are not included when calculating the right-of-use asset and lease liability unless the payments are in-substance fixed.

We recognize lease expense for operating leases on a straight-line basis over the lease term. We recognize lease expense for finance leases as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities using the effective interest method over the lease term.

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):
 
Consolidated Balance Sheet Location
 
June 30, 2019
Right-of-use assets—Operating
Operating lease assets, net
 
$
502

Right-of-use assets—Financing
Property, plant and equipment, net
 
58

Total right-of-use assets
 
 
$
560

 
 
 
 
Current operating lease liabilities
Current operating lease liabilities
 
$
292

Current finance lease liabilities
Other current liabilities
 
1

Non-current operating lease liabilities
Non-current operating lease liabilities
 
202

Non-current finance lease liabilities
Non-current finance lease liabilities
 
58

Total lease liabilities
 
 
$
553



22


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the classification and location of our lease cost on our Consolidated Statements of Operations (in millions):
 
Consolidated Statement of Operations Location
 
Three Months Ended June 30, 2019
 
Six Months Ended June 30, 2019
Operating lease cost (1)
Operating costs and expenses (2)
 
$
140

 
$
277

Finance lease cost:
 
 
 
 
 
Amortization of right-of-use assets
Depreciation and amortization expense
 
1

 
2

Interest on lease liabilities
Interest expense, net of capitalized interest
 
3

 
5

Total lease cost
 
 
$
144

 
$
284

 
(1)
Includes $46 million and $93 million of short-term lease costs and $8 million and $13 million of variable lease costs incurred during the three and six months ended June 30, 2019, respectively.
(2)
Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

Future annual minimum lease payments for operating and finance leases as of June 30, 2019 are as follows (in millions): 
Years Ending December 31,
Operating Leases (1)
 
Finance Leases
2019
$
192

 
$
5

2020
167

 
10

2021
39

 
10

2022
19

 
10

2023
19

 
10

Thereafter
166

 
146

Total lease payments
602

 
191

Less: Interest
(108
)
 
(132
)
Present value of lease liabilities
$
494

 
$
59

 
(1)
Does not include $1.6 billion of legally binding minimum lease payments for vessel charters which were executed as of June 30, 2019 but will commence primarily between 2020 and 2021 and have lease terms of up to seven years.

Future annual minimum lease payments for operating and capital leases as of December 31, 2018, prepared in accordance with accounting standards prior to the adoption of ASC 842, were as follows (in millions):
Years Ending December 31,
Operating Leases (1)
 
Capital Leases (2)
2019 (3)
$
380

 
$
5

2020
184

 
5

2021
238

 
5

2022
264

 
5

2023
264

 
5

Thereafter
999

 
73

Total lease payments
2,329

 
98

Less: Interest

 
(39
)
Present value of lease liabilities
$
2,329

 
$
59

 
(1)
Includes certain lease option renewals that are reasonably assured and payments for certain non-lease components. Also includes $79 million in payments for short-term leases and $1.6 billion in payments for LNG vessel charters which were previously executed but will commence primarily between 2020 and 2021.
(2)
Does not include payments for non-lease components of $98 million.
(3)
Does not include $43 million in aggregate payments we will receive from our LNG vessel subcharters.

23


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

The following table shows the weighted-average remaining lease term (in years) and the weighted-average discount rate for our operating leases and finance leases:
 
June 30, 2019
 
Operating Leases
 
Finance Leases
Weighted-average remaining lease term (in years)
7.2
 
19.3
Weighted-average discount rate (1)
5.4%
 
16.2%
 
(1)
The finance leases commenced prior to the adoption of ASC 842. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

The following table includes other quantitative information for our operating and finance leases (in millions):
 
Six Months Ended June 30, 2019
Cash paid for amounts included in the measurement of lease liabilities:
 
Operating cash flows from operating leases
$
174

Operating cash flows from finance leases
5

Financing cash flows from finance leases

Right-of-use assets obtained in exchange for new operating lease liabilities
106



LNG Vessel Subcharters

From time to time, we sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. We have elected the practical expedient for lessors to combine lease and non-lease components and since the lease component is the predominant component of each arrangement, these subleases are accounted for as operating leases. The subleases have lease terms of up to one year and many contain short-term renewal options exercisable at the discretion of the third party. As of June 30, 2019, we had $13 million in future minimum sublease payments to be received from LNG vessel subcharters, which will be recognized entirely within 2019. We recognize fixed sublease income on a straight-line basis over the lease term of the sublease while variable sublease income is recognized when earned. We recognized $31 million and $68 million of sublease income, including $5 million and $10 million of variable lease payments, during the three and six months ended June 30, 2019, respectively, in other revenues on our Consolidated Statements of Operations.

NOTE 12—REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers during the three and six months ended June 30, 2019 and 2018 (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
LNG revenues
 
$
2,080

 
$
1,516

 
$
4,147

 
$
3,668

Regasification revenues
 
67

 
65

 
133

 
130

Other revenues
 
21

 
13

 
36

 
23

Total revenues from customers
 
2,168

 
1,594

 
4,316

 
3,821

Net derivative gains (losses) (1)
 
93

 
(64
)
 
169

 
(60
)
Other revenues (2)
 
31

 
13

 
68

 
24

Total revenues
 
$
2,292

 
$
1,543

 
$
4,553

 
$
3,785

 
(1)
See Note 6—Derivative Instruments for additional information about our derivatives.
(2)
Includes revenues from LNG vessel subcharters. See Note 11—Leases for additional information about our subleases.


24


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

Contract Assets and Liabilities

The following table shows our contract assets, which we classify as other non-current assets, net on our Consolidated Balance Sheets (in millions):
 
 
June 30,
 
December 31,
 
 
2019
 
2018
Contract assets
 
$
8

 
$



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. Changes in contract assets during the six months ended June 30, 2019 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due.

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Consolidated Balance Sheets (in millions):
 
 
Six Months Ended June 30, 2019
Deferred revenues, beginning of period
 
$
139

Cash received but not yet recognized
 
136

Revenue recognized from prior period deferral
 
(139
)
Deferred revenues, end of period
 
$
136



Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of June 30, 2019 and December 31, 2018:
 
 
June 30, 2019
 
December 31, 2018
 
 
Unsatisfied Transaction Price (in billions)
 
Weighted Average Recognition Timing (years) (1)
 
Unsatisfied Transaction Price (in billions)
 
Weighted Average Recognition Timing (years) (1)
LNG revenues
 
$
108.4

 
11
 
$
106.6

 
11
Regasification revenues
 
2.5

 
5
 
2.6

 
6
Total revenues
 
$
110.9

 

 
$
109.2

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

We have elected the following exemptions which omit certain potential future sources of revenue from the table above:
(1)
We omit from the table above all performance obligations that are part of a contract that has an original expected duration of one year or less.
(2)
We omit from the table above all variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation when that performance obligation qualifies as a series. The table above excludes substantially all variable consideration under our SPAs and TUAs. The amount of revenue from variable fees that is not included in the transaction price will vary based on the future prices of Henry Hub throughout the contract terms, to the extent customers elect to take delivery of their LNG, and adjustments to the consumer price index. 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 52% and 55% of our LNG revenues from contracts with a duration of over one year during the three months ended June 30, 2019 and 2018, respectively, and approximately 55% of our LNG revenues from contracts with a duration of over one year during

25


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

each of the six months ended June 30, 2019 and 2018, were related to variable consideration received from customers. During each of the three and six months ended June 30, 2019 and 2018, approximately 3% of our regasification revenues were related to variable consideration received from customers.

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

NOTE 13—INCOME TAXES

We recorded an income tax benefit of zero and $3 million during the three months ended June 30, 2019 and 2018, respectively, and an income tax provision of $3 million and $12 million during the six months ended June 30, 2019 and 2018, respectively. Changes in the income tax recorded between comparative periods are primarily attributable to changes in the income earned and tax transfer pricing applied to our U.K. integrated marketing function.

The effective tax rates during the three and six months ended June 30, 2019 and 2018 were lower than the 21% federal statutory rate during the 2019 and 2018 interim periods primarily as a result of maintaining a valuation allowance against our federal and state net deferred tax assets. Due to historical losses and other available evidence related to our ability to generate taxable income, we continue to maintain a valuation allowance against our federal and state net deferred tax assets at June 30, 2019.

NOTE 14—SHARE-BASED COMPENSATION
  
We have granted restricted stock shares, restricted stock units, performance stock units and phantom units to employees and non-employee directors under the 2011 Incentive Plan, as amended (the “2011 Plan”) and the 2015 Employee Inducement Incentive Plan.

For the six months ended June 30, 2019, we granted 1.3 million restricted stock units and 0.2 million performance stock units at target performance under the 2011 Plan to certain employees. Restricted stock units are stock awards that vest over a service period of three years and entitle the holder to receive shares of our common stock upon vesting, subject to restrictions on transfer and to a risk of forfeiture if the recipient terminates employment with us prior to the lapse of the restrictions. Performance stock units provide for cliff vesting after a period of three years with payouts based on metrics dependent upon market and performance achieved over the period from January 1, 2019 through December 31, 2021 compared to pre-established performance targets. The settlement amounts of the awards are based on market and performance metrics which include cumulative distributable cash flow per share, and in certain circumstances, total shareholder return (“TSR”) of our common stock. Where applicable, the compensation for performance stock units is based on fair value assigned to the market metric of TSR using a Monte Carlo model upon grant, which remains constant through the vesting period, and a performance metric, which will vary due to changing estimates regarding the expected achievement of the performance metric of cumulative distributable cash flow per share. The number of shares that may be earned at the end of the vesting period ranges from 25% up to 300% of the target award amount if the threshold performance is met. Both restricted stock units and performance stock units will be settled in Cheniere common stock (on a one-for-one basis) and are classified as equity awards.

Total share-based compensation consisted of the following (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
Share-based compensation costs, pre-tax:
 
 
 
 
 
 
 
 
Equity awards
 
$
32

 
$
22

 
$
61

 
$
39

Liability awards
 
2

 
15

 
5

 
32

Total share-based compensation
 
34


37


66


71

Capitalized share-based compensation
 
(1
)
 
(7
)
 
(5
)
 
(13
)
Total share-based compensation expense
 
$
33


$
30


$
61


$
58

Tax benefit associated with share-based compensation expense
 
$

 
$

 
$
1

 
$
2




26


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

NOTE 15—NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

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

The following table reconciles basic and diluted weighted average common shares outstanding for the three and six months ended June 30, 2019 and 2018 (in millions, except per share data):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
Weighted average common shares outstanding:
 
 
 
 
 
 
 
 
Basic
 
257.4

 
242.8

 
257.3

 
239.2

Dilutive unvested stock
 

 

 
1.3

 
2.5

Diluted
 
257.4

 
242.8

 
258.6

 
241.7

 
 
 
 
 
 
 
 
 
Basic net income (loss) per share attributable to common stockholders
 
$
(0.44
)
 
$
(0.07
)
 
$
0.11

 
$
1.42

Diluted net income (loss) per share attributable to common stockholders
 
$
(0.44
)
 
$
(0.07
)
 
$
0.11

 
$
1.40



Potentially dilutive securities that were not included in the diluted net income (loss) per share computations because their effects would have been anti-dilutive were as follows (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2019
 
2018
 
2019
 
2018
Unvested stock (1)
 
3.8

 
5.2

 
3.8

 
2.6

Convertible notes (2)
 
17.8

 
17.2

 
17.8

 
17.2

Total potentially dilutive common shares
 
21.6

 
22.4

 
21.6

 
19.8

 
(1)
Does not include 0.6 million shares for each of the three and six months ended June 30, 2019 and 0.4 million shares for each of the three and six months ended June 30, 2018 of unvested stock because the performance conditions had not yet been satisfied as of June 30, 2019 and 2018, respectively.
(2)
Includes number of shares in aggregate issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes and the 2045 Cheniere Convertible Senior Notes. There were no shares included in the computation of diluted net income (loss) per share for the 2025 CCH HoldCo II Convertible Senior Notes because substantive non-market-based contingencies underlying the eligible conversion date have not been met as of June 30, 2019.

NOTE 16—COMMITMENTS AND CONTINGENCIES

We have various contractual obligations which are recorded as liabilities in our Consolidated Financial Statements. Other items, such as certain purchase commitments and other executed contracts which do not meet the definition of a liability as of June 30, 2019, are not recognized as liabilities but require disclosures in our Consolidated Financial Statements.

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.


27


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

Parallax Litigation

In 2015, our wholly owned subsidiary, Cheniere LNG Terminals, LLC (“CLNGT”), entered into discussions with Parallax Enterprises, LLC (“Parallax Enterprises”) regarding the potential joint development of two liquefaction plants in Louisiana (the “Potential Liquefaction Transactions”). While the parties negotiated regarding the Potential Liquefaction Transactions, CLNGT loaned Parallax Enterprises approximately $46 million, as reflected in a secured note dated April 23, 2015, as amended on June 30, 2015, September 30, 2015 and November 4, 2015 (the “Secured Note”). The Secured Note was secured by all assets of Parallax Enterprises and its subsidiary entities. On June 30, 2015, Parallax Enterprises’ parent entity, Parallax Energy LLC (“Parallax Energy”), executed a Pledge and Guarantee Agreement further securing repayment of the Secured Note by providing a parent guaranty and a pledge of all of the equity of Parallax Enterprises in satisfaction of the Secured Note (the “Pledge Agreement”). CLNGT and Parallax Enterprises never executed a definitive agreement to pursue the Potential Liquefaction Transactions. The Secured Note matured on December 11, 2015, and Parallax Enterprises failed to make payment. On February 3, 2016, CLNGT filed an action against Parallax Energy, Parallax Enterprises and certain of Parallax Enterprises’ subsidiary entities, styled Cause No. 4:16-cv-00286, Cheniere LNG Terminals, LLC v. Parallax Energy LLC, et al., in the United States District Court for the Southern District of Texas (the “Texas Federal Suit”). CLNGT asserted claims in the Texas Federal Suit for (1) recovery of all amounts due under the Secured Note and (2) declaratory relief establishing that CLNGT is entitled to enforce its rights under the Secured Note and Pledge Agreement in accordance with each instrument’s terms and that CLNGT has no obligations of any sort to Parallax Enterprises concerning the Potential Liquefaction Transactions. On March 11, 2016, Parallax Enterprises and the other defendants in the Texas Federal Suit moved to dismiss the suit for lack of subject matter jurisdiction. On August 2, 2016, the court denied the defendants’ motion to dismiss without prejudice and permitted the parties to pursue jurisdictional discovery.

On March 11, 2016, Parallax Enterprises filed a suit against us and CLNGT styled Civil Action No. 62-810, Parallax Enterprises LLP v. Cheniere Energy, Inc. and Cheniere LNG Terminals, LLC, in the 25th Judicial District Court of Plaquemines Parish, Louisiana (the “Louisiana Suit”), wherein Parallax Enterprises asserted claims for breach of contract, fraudulent inducement, negligent misrepresentation, detrimental reliance, unjust enrichment and violation of the Louisiana Unfair Trade Practices Act. Parallax Enterprises predicated its claims in the Louisiana Suit on an allegation that we and CLNGT breached a purported agreement to jointly develop the Potential Liquefaction Transactions. Parallax Enterprises sought $400 million in alleged economic damages and rescission of the Secured Note. On April 15, 2016, we and CLNGT removed the Louisiana Suit to the United States District Court for the Eastern District of Louisiana, which subsequently transferred the Louisiana Suit to the United States District Court for the Southern District of Texas, where it was assigned Civil Action No. 4:16-cv-01628 and transferred to the same judge presiding over the Texas Federal Suit for coordinated handling. On August 22, 2016, Parallax Enterprises voluntarily dismissed all claims asserted against CLNGT and us in the Louisiana Suit without prejudice to refiling.

On July 27, 2017, the Parallax entities named as defendants in the Texas Federal Suit reurged their motion to dismiss and simultaneously filed counterclaims against CLNGT and third party claims against us for breach of contract, breach of fiduciary duty, promissory estoppel, quantum meruit and fraudulent inducement of the Secured Note and Pledge Agreement, based on substantially the same factual allegations Parallax Enterprises made in the Louisiana Suit. These Parallax entities also simultaneously filed an action styled Cause No. 2017-49685, Parallax Enterprises, LLC, et al. v. Cheniere Energy, Inc., et al., in the 61st District Court of Harris County, Texas (the “Texas State Suit”), which asserts substantially the same claims these entities asserted in the Texas Federal Suit. On July 31, 2017, CLNGT withdrew its opposition to the dismissal of the Texas Federal Suit without prejudice on jurisdictional grounds and the federal court subsequently dismissed the Texas Federal Suit without prejudice. We and CLNGT simultaneously filed an answer and counterclaims in the Texas State Suit, asserting the same claims CLNGT had previously asserted in the Texas Federal Suit. Additionally, CLNGT filed third party claims against Parallax principals Martin Houston, Christopher Bowen Daniels, Howard Candelet and Mark Evans, as well as Tellurian Investments, Inc., Driftwood LNG, LLC, Driftwood LNG Pipeline LLC and Tellurian Services LLC, formerly known as Parallax Services LLC, including claims for tortious interference with CLNGT’s collateral rights under the Secured Note and Pledge Agreement, fraudulent transfer, conspiracy/aiding and abetting. Discovery in the Texas State Suit is ongoing. Trial is currently set for February 2020.
 
On February 15, 2019, we filed an action with CLNGT against Charif Souki, our former Chairman of the Board and Chief Executive Officer, styled, Cause No. 2019-11529, Cheniere Energy, Inc. and Cheniere LNG Terminals, LLC v. Charif Souki, in the 55th District Court of Harris County, Texas, which asserts claims of breach of fiduciary duties, fraudulent transfer, tortious interference with CLNGT’s collateral rights under the Secured Note and Pledge Agreement and conspiracy/aiding and abetting. On April 29, 2019, the court consolidated the Souki matter with the earlier filed pending case against Parallax, Tellurian and the individual defendants in the Texas State Suit.


28


CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(unaudited)

We do not expect that the resolution of any of the foregoing litigation will have a material adverse impact on our financial results.

NOTE 17—CUSTOMER CONCENTRATION
  
The following table shows customers with revenues of 10% or greater of total revenues from external customers and customers with accounts receivable balances of 10% or greater of total accounts receivable from external customers:
 
 
Percentage of Total Revenues from External Customers
 
Percentage of Accounts Receivable from External Customers
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
June 30,
 
December 31,
 
 
2019
 
2018
 
2019
 
2018
 
2019
 
2018
Customer A
 
17%
 
21%
 
18%
 
19%
 
11%
 
21%
Customer B
 
11%
 
17%
 
11%
 
14%
 
15%
 
14%
Customer C
 
11%
 
18%
 
12%
 
22%
 
15%
 
18%
Customer D
 
12%
 
16%
 
13%
 
11%
 
14%
 
*
Customer E
 
*
 
*