Sabine Pass Liquefaction, LLC - FORM 10-Q

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EX-32.1 - EXHIBIT 32.1 - Sabine Pass Liquefaction, LLC	exhibit321spl2016form10q3r.htm
EX-32.2 - EXHIBIT 32.2 - Sabine Pass Liquefaction, LLC	exhibit322spl2016form10q3r.htm
EX-31.2 - EXHIBIT 31.2 - Sabine Pass Liquefaction, LLC	exhibit312spl2016form10q3r.htm
EX-31.1 - EXHIBIT 31.1 - Sabine Pass Liquefaction, LLC	exhibit311spl2016form10q3r.htm
EX-10.3 - EXHIBIT 10.3 - Sabine Pass Liquefaction, LLC	exhibit103spl2016form10-q3.htm
EX-10.2 - EXHIBIT 10.2 - Sabine Pass Liquefaction, LLC	exhibit102spl2016form10-q3.htm
EX-10.1 - EXHIBIT 10.1 - Sabine Pass Liquefaction, LLC	exhibit101spl2016form10-q3.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2016

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

For the transition period from to

Sabine Pass Liquefaction, LLC

(Exact name of registrant as specified in its charter)



Delaware	333-192373	27-3235920
(State or other jurisdiction of incorporation or organization)	(Commission File Number)	(I.R.S. Employer Identification No.)

700 Milam Street, Suite 1900 Houston, Texas		77002
(Address of principal executive offices)		(Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

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 x

Note: As of January 1, 2016, the registrant is a voluntary filer not subject to the filing requirements of Sections 13 or 15(d) of the Securities Exchange Act of 1934. However, 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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes x No ¨

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



Large accelerated filer ¨	Accelerated filer ¨
Non-accelerated filer x	Smaller reporting company ¨
(Do not check if a smaller reporting company)

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

Indicate the number of shares outstanding of the issuer’s classes of common stock, as of the latest practicable date: Not applicable

SABINE PASS LIQUEFACTION, LLC

TABLE OF CONTENTS



	Definitions	1
Part I. Financial Information
Item 1.	Financial Statements	2
	Balance Sheets	2
	Statements of Operations	3
	Statement of Member’s Equity	4
	Statements of Cash Flows	5
	Notes to Financial Statements	6

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

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	30

Item 4.	Controls and Procedures	31

Part II. Other Information
Item 1.	Legal Proceedings	32

Item 1A.	Risk Factors	32

Item 5.	Other Information	32

Item 6.	Exhibits	33

	Signatures	34

DEFINITIONS

As commonly used in the liquefied natural gas industry, to the extent applicable and 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
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 consisting primarily of methane (CH₄) that is in liquid form at near atmospheric pressure
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		Securities and Exchange Commission
SPA		LNG sale and purchase agreement
Train		an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA		terminal use agreement

Company Abbreviations



Cheniere		Cheniere Energy, Inc.
Cheniere Investments		Cheniere Energy Investments, LLC
Cheniere Marketing		Cheniere Marketing, LLC and subsidiaries
Cheniere Partners		Cheniere Energy Partners, L.P.
Cheniere Terminals		Cheniere LNG Terminals, LLC
CTPL		Cheniere Creole Trail Pipeline, L.P.
SPLNG		Sabine Pass LNG, L.P.

Unless the context requires otherwise, references to “SPL,” the “Company,” “we,” “us” and “our” refer to Sabine Pass Liquefaction, LLC.


PART I.	FINANCIAL INFORMATION


ITEM 1.	FINANCIAL STATEMENTS

SABINE PASS LIQUEFACTION, LLC

BALANCE SHEETS

(in thousands)



	September 30,		December 31,
	2016		2015
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	—	$	—
Restricted cash	325,630		189,260
Accounts and other receivables	50,966		577
Accounts receivable—affiliate	56,986		2,457
Advances to affiliate	31,002		28,312
Inventory	51,715		5,742
Other current assets	11,256		8,412
Other current assets—affiliate	5,293		—
Total current assets	532,848		234,760

Property, plant and equipment, net	11,491,279		9,841,407
Debt issuance costs, net	62,349		132,091
Non-current derivative assets	11,247		30,304
Other non-current assets	179,832		194,818
Total assets	$	12,277,555	$	10,433,380

LIABILITIES AND MEMBER’S EQUITY
Current liabilities
Accounts payable	$	17,130	$	13,420
Accrued liabilities	326,815		201,559
Current debt	98,500		15,000
Due to affiliates	42,556		53,848
Derivative liabilities	7,459		6,430
Total current liabilities	492,460		290,257

Long-term debt, net	11,330,473		9,205,559
Non-current derivative liabilities	9,583		2,884
Other non-current liabilities—affiliate	3,578		3,393

Member’s equity	441,461		931,287
Total liabilities and member’s equity	$	12,277,555	$	10,433,380

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

SABINE PASS LIQUEFACTION, LLC

STATEMENTS OF OPERATIONS

(in thousands)

(unaudited)



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2016			2015			2016			2015
Revenues
LNG revenues	$	248,188		$	—		$	333,542		$	—
LNG revenues—affiliate	16,236			—			16,236			—
Total revenues	264,424			—			349,778			—


Operating costs and expenses
Cost (cost recovery) of sales (excluding depreciation and amortization expense shown separately below)	161,829			(32,106		)	217,567			(32,176		)
Cost of sales—affiliate	3,245			—			3,890			—
Operating and maintenance expense	24,588			1,623			40,606			4,655
Operating and maintenance expense—affiliate	43,468			328			66,230			456
Terminal use agreement maintenance expense (recovery)	72			(837		)	(546		)	16,684
Terminal use agreement maintenance expense—affiliate	—			130			208			308
Development expense	1			113			137			2,631
Development expense—affiliate	87			152			484			562
General and administrative expense	1,818			1,307			5,472			4,027
General and administrative expense—affiliate	18,942			18,938			51,824			58,304
Depreciation and amortization expense	25,749			461			37,863			1,279
Total operating costs and expenses (recoveries)	279,799			(9,891		)	423,735			56,730

Income (loss) from operations	(15,375		)	9,891			(73,957		)	(56,730		)

Other income (expense)
Interest expense, net of capitalized interest	(65,939		)	(11,952		)	(99,203		)	(31,261		)
Loss on early extinguishment of debt	(25,765		)	—			(52,070		)	(96,273		)
Derivative gain (loss), net	2,557			(10,872		)	(13,473		)	(46,541		)
Other income	179			98			429			320
Total other expense	(88,968		)	(22,726		)	(164,317		)	(173,755		)

Net loss	$	(104,343	)	$	(12,835	)	$	(238,274	)	$	(230,485	)

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

SABINE PASS LIQUEFACTION, LLC

STATEMENT OF MEMBER’S EQUITY

(in thousands)

(unaudited)



	Sabine Pass LNG-LP, LLC			Total Member’s Equity
Balance at December 31, 2015	$	931,287		$	931,287
Capital contributions from Cheniere Partners	1,250			1,250
Non-cash distributions to affiliates	(252,802		)	(252,802		)
Net loss	(238,274		)	(238,274		)
Balance at September 30, 2016	$	441,461		$	441,461

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

SABINE PASS LIQUEFACTION, LLC

STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)



	Nine Months Ended September 30,
	2016			2015
Cash flows from operating activities
Net loss	$	(238,274	)	$	(230,485	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Non-cash terminal use agreement maintenance expense	160			16,610
Depreciation and amortization expense	37,863			1,279
Loss on early extinguishment of debt	52,070			96,273
Total losses on derivatives, net	35,635			13,136
Net cash used for settlement of derivative instruments	(8,031		)	(40,990		)
Changes in restricted cash for certain operating activities	157,291			230,187
Changes in operating assets and liabilities:
Accounts and other receivables	(31,022		)	8
Accounts receivable—affiliate	(36,650		)	(78		)
Advances to affiliate	—			(12,654		)
Inventory	(28,296		)	(41		)
Accounts payable and accrued liabilities	67,039			(42,179		)
Due to affiliates	3,885			(10,029		)
Other, net	(7,044		)	(1,840		)
Other—affiliate	(4,626		)	(19,197		)
Net cash provided by (used in) operating activities	—			—

Cash flows from investing activities
Property, plant and equipment, net	(1,872,975		)	(2,094,567		)
Use of restricted cash for the acquisition of property, plant and equipment	1,905,102			2,144,821
Other	(32,127		)	(50,254		)
Net cash provided by (used in) investing activities	—			—

Cash flows from financing activities
Proceeds from issuances of debt	4,968,500			2,250,000
Repayments of debt	(2,730,000		)	—
Debt issuance and deferred financing costs	(40,693		)	(176,002		)
Investment in restricted cash	(2,198,763		)	(2,089,295		)
Capital contributions from Cheniere Partners	1,250			15,297
Other	(294		)	—
Net cash provided by (used in) financing activities	—			—

Net increase (decrease) in cash and cash equivalents	—			—
Cash and cash equivalents—beginning of period	—			—
Cash and cash equivalents—end of period	$	—		$	—

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

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS

(unaudited)

NOTE 1—BASIS OF PRESENTATION

The accompanying unaudited Financial Statements of SPL 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. 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 had no effect on our overall financial position, operating results or cash flows.

In 2016, we started production at our natural gas liquefaction facilities at the Sabine Pass LNG terminal located in Cameron Parish, Louisiana (the “Liquefaction Project”). As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project, and other related costs to convert natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs.

Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities. During the three and nine months ended September 30, 2016, we received 70% and 77%, respectively, of our net LNG revenues from one SPA customer.

Results of operations for the three and nine months ended September 30, 2016 are not necessarily indicative of the operating results that will be realized for the year ending December 31, 2016.

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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.

For further information, refer to the Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, 2015.

NOTE 2—RESTRICTED CASH

Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. As of September 30, 2016 and December 31, 2015, restricted cash consisted of the following (in thousands):



	September 30,		December 31,
	2016		2015
Current restricted cash
Liquefaction Project	$	325,630	$	189,260

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 3—ACCOUNTS AND OTHER RECEIVABLES

As of September 30, 2016 and December 31, 2015, accounts and other receivables consisted of the following (in thousands):



	September 30,		December 31,
	2016		2015
Trade receivable	$	38,432	$	—
Interest receivable	53		7
Other accounts receivable	12,481		570
Total accounts and other receivables	$	50,966	$	577

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. As of September 30, 2016, the entire balance of our trade receivable was from a single SPA customer.

NOTE 4—INVENTORY

As of September 30, 2016 and December 31, 2015, inventory consisted of the following (in thousands):



	September 30,		December 31,
	2016		2015
Natural gas	$	4,181	$	5,724
LNG	25,280		—
Materials and other	22,254		18
Total inventory	$	51,715	$	5,742

NOTE 5—PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands):



	September 30,			December 31,
	2016			2015
LNG terminal costs
LNG terminal	$	5,264,538		$	42,220
LNG terminal construction-in-process	6,254,085			9,795,309
Accumulated depreciation	(32,493		)	(789		)
Total LNG terminal costs, net	11,486,130			9,836,740
Fixed assets
Furniture and fixtures	1,446			1,154
Computer software	4,144			3,782
Machinery and equipment	405			339
Vehicles	2,419			1,405
Other	720			390
Accumulated depreciation	(3,985		)	(2,403		)
Total fixed assets, net	5,149			4,667
Property, plant and equipment, net	$	11,491,279		$	9,841,407

During the three and nine months ended September 30, 2016, we realized offsets to LNG terminal costs of $58.7 million and $201.0 million, respectively, that were related to the sale of commissioning cargoes because these amounts were earned prior to the start of commercial operations, during the testing phase for the construction of Trains 1 and 2 of the Liquefaction Project.

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 one of our credit facilities (“Interest Rate Derivatives”);

SABINE PASS LIQUEFACTION, LLC

NOTES TO 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 (“Financial Liquefaction Supply Derivatives”, and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”); and


•	commodity derivatives to hedge the exposure to price risk attributable to future sales of our LNG inventory (“Natural Gas Derivatives”).

None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Operations.

The following table (in thousands) shows the fair value of the derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2016 and December 31, 2015, which are classified as other current assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Balance Sheets.



	Fair Value Measurements as of
	September 30, 2016											December 31, 2015
	Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total			Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
Interest Rate Derivatives liability	$	—		$	(15,948	)	$	—	$	(15,948	)	$	—	$	(8,740	)	$	—	$	(8,740	)
Liquefaction Supply Derivatives asset (liability)	(105		)	(275		)	12,480		12,100			—		(25		)	32,492		32,467
Natural Gas Derivatives asset	—			—			—		—			—		29			—		29

We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. The estimated fair values of our Natural Gas Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data.

The fair value of substantially all of our Physical Liquefaction Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of our Physical Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of our Physical Liquefaction Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a particular Physical Liquefaction Supply Derivatives contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, the fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. Internal fair value models include conditions precedent to the respective long-term natural gas supply contracts. As of September 30, 2016 and December 31, 2015, some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow. Accordingly, our internal fair value models are based on market prices that equate to our own contractual pricing due to: (1) the inactive and unobservable market and (2) conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas supply contracts as of the reporting date.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

As all of our Physical Liquefaction Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2016:



	Net Fair Value Asset (in thousands)	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Physical Liquefaction Supply Derivatives	$12,480	Income Approach	Basis Spread	$(0.35) - $(0.03)

The following table (in thousands) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2016 and 2015:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Balance, beginning of period	$	22,434		$	440		$	32,492		$	342
Realized and mark-to-market losses:
Included in cost of sales (1)	(10,567		)	32,177			(20,482		)	32,204
Purchases and settlements:
Purchases	968			—			968			—
Settlements (1)	(308		)	(71		)	(741		)	—
Transfers out of Level 3 (2)	(47		)	—			243			—
Balance, end of period	$	12,480		$	32,546		$	12,480		$	32,546
Change in unrealized gains relating to instruments still held at end of period	$	(10,567	)	$	—		$	(19,763	)	$	—


(1)	Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the nine months ended September 30, 2016.


(2)	Transferred to Level 2 as a result of observable market for the underlying natural gas supply contracts.

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 net settlement. 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.

Interest Rate Derivatives

We have entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the credit facilities we entered into in June 2015 (the “2015 Credit Facilities”). The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 Credit Facilities.

In March 2015, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the previous credit facilities.

As of September 30, 2016, 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

Interest Rate Derivatives

$20.0 million

$628.8 million

August 14, 2012

July 31, 2019

1.98%

One-month LIBOR

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets:



		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2016			December 31, 2015
Interest Rate Derivatives	Derivative liabilities	$	(6,376	)	$	(5,940	)
Interest Rate Derivatives	Non-current derivative liabilities	(9,572		)	(2,800		)

The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative gain (loss), net on our Statements of Operations during the three and nine months ended September 30, 2016 and 2015:



	Three Months Ended September 30,					Nine Months Ended September 30,
	2016		2015			2016			2015
Interest Rate Derivatives gain (loss)	$	2,557	$	(10,872	)	$	(13,473	)	$	(46,541	)

Commodity Derivatives

Liquefaction Supply Derivatives

We have entered into 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 terms of the physical natural gas supply contracts primarily range from approximately one to seven years and commence upon the satisfaction of certain conditions precedent, including but not limited to the date of first commercial operation of specified Trains of the Liquefaction Project. We recognize our Physical Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Physical Liquefaction Supply Derivatives are reported in earnings. As of September 30, 2016, we have secured up to approximately 1,982.0 million MMBtu of natural gas feedstock through natural gas supply contracts. The notional natural gas position of our Physical Liquefaction Supply Derivatives was approximately 1,069.0 million MMBtu as of September 30, 2016.

Our Financial Liquefaction Supply Derivatives are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our Financial Liquefaction Supply Derivatives activities.

Natural Gas Derivatives

Our Natural Gas Derivatives were executed through over-the-counter contracts which were subject to nominal credit risk as these transactions settled on a daily margin basis with investment grade financial institutions. We were required by these financial institutions to use margin deposits as credit support for our Natural Gas Derivatives activities. As of September 30, 2016, we did not have any open Natural Gas Derivatives positions or margin deposits at financial institutions.

We recognize all commodity derivative instruments, including our Liquefaction Supply Derivatives and our Natural Gas Derivatives (collectively, “Commodity Derivatives”), as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Commodity Derivatives are reported in earnings.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets:



	September 30, 2016								December 31, 2015
	Liquefaction Supply Derivatives (1)			Natural Gas Derivatives		Total			Liquefaction Supply Derivatives			Natural Gas Derivatives (2)		Total
Balance Sheet Location
Other current assets	$	1,947		$	—	$	1,947		$	2,737		$	29	$	2,766
Non-current derivative assets	11,247			—		11,247			30,304			—		30,304
Total derivative assets	13,194			—		13,194			33,041			29		33,070

Derivative liabilities	(1,083		)	—		(1,083		)	(490		)	—		(490		)
Non-current derivative liabilities	(11		)	—		(11		)	(84		)	—		(84		)
Total derivative liabilities	(1,094		)	—		(1,094		)	(574		)	—		(574		)

Derivative asset, net	$	12,100		$	—	$	12,100		$	32,467		$	29	$	32,496


(1)	Does not include collateral of $1.5 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of September 30, 2016.


(2)	Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015.

The following table (in thousands) shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Statements of Operations during the three and nine months ended September 30, 2016 and 2015:



		Three Months Ended					Nine Months Ended
		September 30,					September 30,
	Statement of Operations Location	2016			2015		2016			2015
Liquefaction Supply Derivatives gain	LNG revenues	$	374		$	—	$	368		$	—
Liquefaction Supply Derivatives gain (loss) (1)	Cost (cost recovery) of sales	(10,416		)	32,103		(22,680		)	32,184
Natural Gas Derivatives gain	Operating and maintenance expense	—			778		150			1,221

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

The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position.

Balance Sheet Presentation

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



	Gross Amounts Recognized			Gross Amounts Offset in the Balance Sheets			Net Amounts Presented in the Balance Sheets
Offsetting Derivative Assets (Liabilities)	Gross Amounts Recognized			Gross Amounts Offset in the Balance Sheets			Net Amounts Presented in the Balance Sheets
As of September 30, 2016
Interest Rate Derivatives	$	(15,948	)	$	—		$	(15,948	)
Liquefaction Supply Derivatives	13,740			(546		)	13,194
Liquefaction Supply Derivatives	(2,803		)	1,709			(1,094		)
As of December 31, 2015
Interest Rate Derivatives	$	(8,740	)	$	—		$	(8,740	)
Liquefaction Supply Derivatives	33,636			(595		)	33,041
Liquefaction Supply Derivatives	(574		)	—			(574		)
Natural Gas Derivatives	152			(123		)	29

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 7—OTHER NON-CURRENT ASSETS

As of September 30, 2016 and December 31, 2015, other non-current assets consisted of the following (in thousands):



	September 30,		December 31,
	2016		2015
Advances made under EPC and non-EPC contracts	$	13,678	$	32,049
Advances made to municipalities for water system enhancements	95,551		89,953
Tax-related payments and receivables	3,185		5,535
Information technology service assets	23,186		24,166
Other	44,232		43,115
Total other non-current assets	$	179,832	$	194,818

NOTE 8—ACCRUED LIABILITIES

As of September 30, 2016 and December 31, 2015, accrued liabilities consisted of the following (in thousands):



	September 30,		December 31,
	2016		2015
Interest costs and related debt fees	$	140,716	$	135,336
Liquefaction Project costs	185,961		66,223
Other accrued liabilities	138		—
Total accrued liabilities	$	326,815	$	201,559

NOTE 9—DEBT

As of September 30, 2016 and December 31, 2015, our debt consisted of the following (in thousands):



	September 30,			December 31,
	2016			2015
Long-term debt
5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7,573 and $8,718	$	2,007,573		$	2,008,718
6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”)	1,000,000			1,000,000
5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5,844 and $6,392	1,505,844			1,506,392
5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”)	2,000,000			2,000,000
5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”)	2,000,000			2,000,000
5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”)	1,500,000			—
5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”)	1,500,000			—
2015 Credit Facilities	—			845,000
Unamortized debt issuance costs (1)	(182,944		)	(154,551		)
Total long-term debt, net	11,330,473			9,205,559

Current debt
$1.2 billion Working Capital Facility (“Working Capital Facility”)	98,500			15,000
Total debt, net	$	11,428,973		$	9,220,559

(1)

Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

2016 Debt Issuances and Redemptions

Senior Notes

In June and September 2016, we issued the 2026 Senior Notes and the 2027 Senior Notes, respectively, for aggregate principal amounts of $1.5 billion each. Net proceeds of the offerings of the 2026 Senior Notes and 2027 Senior Notes were approximately $1.3 billion and $1.4 billion, respectively, after deducting commissions, fees and expenses and incremental interest required under the respective senior notes during construction. The net proceeds were used to prepay a portion (for the 2026 Senior Notes) or all (for the 2027 Senior Notes) outstanding borrowings and terminate commitments under the 2015 Credit Facilities, resulting in a write-off of debt issuance costs associated with the 2015 Credit Facilities of $25.8 million and $51.8 million during the three and nine months ended September 30, 2016, respectively. The remaining proceeds from the 2027 Senior Notes are being used to pay a portion of the capital costs in connection with the construction of Trains 1 through 5 of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2015 Credit Facilities. The 2026 Senior Notes and 2027 Senior Notes accrue interest at fixed rates of 5.875% and 5.00%, respectively, and interest is payable semi-annually in arrears. The terms of the 2026 Senior Notes and 2027 Senior Notes are governed by the same common indenture as our other senior notes, which contains customary terms and events of default, covenants and redemption terms.

In connection with the issuance of the 2026 Senior Notes and the 2027 Senior Notes, we entered into registration rights agreements (the “Registration Rights Agreements”). Under the terms of the Registration Rights Agreements, we have agreed, and any future guarantors will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to offers to exchange any and all of the 2026 Senior Notes and 2027 Senior Notes for like aggregate principal amounts of our debt securities with terms identical in all material respects to the respective senior notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), within 360 days after June 14, 2016 and September 23, 2016, respectively. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective shelf registration statements relating to resales of the 2026 Senior Notes and the 2027 Senior Notes. We will be obligated to pay additional interest on these senior notes if we fail to comply with our obligation to register them within the specified time period.

Credit Facilities

Below is a summary of our credit facilities outstanding as of September 30, 2016 (in thousands):



	2015 Credit Facilities		Working Capital Facility
Original facility size	$	4,600,000	$	1,200,000
Outstanding balance	—		98,500
Commitments prepaid or terminated	2,643,867		—
Letters of credit issued	—		337,044
Available commitment	$	1,956,133	$	764,456

Interest rate	LIBOR plus 1.30% - 1.75% or base rate plus 1.75%		LIBOR plus 1.75% or base rate plus 0.75%
Maturity date	Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date		December 31, 2020, with various terms for underlying loans

Interest Expense

Total interest expense consisted of the following (in thousands):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
Total interest cost	$	168,228		$	141,068		$	469,546		$	387,963
Capitalized interest	(102,289		)	(129,116		)	(370,343		)	(356,702		)
Total interest expense, net	$	65,939		$	11,952		$	99,203		$	31,261

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Fair Value Disclosures

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



	September 30, 2016				December 31, 2015
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior Notes, net of premium (1)	$	11,513,417	$	12,281,145	$	8,515,110	$	7,469,718
Credit facilities (2)	98,500		98,500		860,000		860,000


(1)	Includes 2021 Senior Notes, net of premium; 2022 Senior Notes; 2023 Senior Notes, net of premium; 2024 Senior Notes; 2025 Senior Notes; 2026 Senior Notes; and 2027 Senior Notes (collectively, the “Senior Notes”). The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments.


(2)	Includes 2015 Credit Facilities and 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.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 10—RELATED PARTY TRANSACTIONS

Below is a summary of our related party transactions as reported on our Statements of Operations for the three and nine months ended September 30, 2016 and 2015 (in thousands):



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2016		2015		2016		2015
LNG revenues—affiliate
Cheniere Marketing Master SPA	$	16,236	$	—	$	16,236	$	—

Cost of sales—affiliate
Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”)	1,815		—		2,460		—
Fees under the Pre-commercial LNG Marketing Agreement	1,430		—		1,430		—
Total cost of sales—affiliate	3,245		—		3,890		—

Operating and maintenance expense—affiliate
TUA	18,522		—		28,764		—
Natural Gas Transportation Agreement	16,660		—		24,344		—
Services Agreements	8,051		93		12,530		221
LNG Site Sublease Agreement	235		235		592		235
Total operating and maintenance expense—affiliate	43,468		328		66,230		456

Terminal use agreement maintenance expense—affiliate
TUA	—		130		208		308

Development expense—affiliate
Services Agreements	87		152		369		562
LNG Site Sublease Agreement	—		—		115		—
Total development expense—affiliate	87		152		484		562

General and administrative expense—affiliate
Services Agreements	18,942		18,938		51,824		58,048
LNG Site Sublease Agreement	—		—		—		241
Other agreements	—		—		—		15
Total general and administrative expense—affiliate	18,942		18,938		51,824		58,304

LNG Terminal-Related Agreements

Terminal Use Agreements

We have entered into a TUA with SPLNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG. We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”), continuing until at least 20 years after we deliver our first commercial cargo at our facilities under construction. We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA. In connection with the assignment, we, Cheniere Investments and SPLNG also entered into the TURA pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees required by the TUA to SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. The percentage of the TUA Fees payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the TUA Fees payable by us will increase by the amount that Cheniere Investments’ percentage decreases. In May 2016, upon substantial completion of Train 1 of the Liquefaction Project, Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was reduced from 100% to 75% and our percentage of all TUA Fees payable to SPLNG was increased from zero to 25% in accordance with the TURA. Subsequently, in September 2016, upon substantial completion of Train 2 of the Liquefaction Project,

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was further reduced from 75% to 50% and our percentage of all TUA Fees payable to SPLNG was further increased from 25% to 50% in accordance with the TURA. Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA. Cargo loading fees incurred under this agreement are recorded as cost of sales—affiliate, except for the portion related to commissioning activities which is capitalized as LNG terminal construction-in-process.

In connection with our TUA, we are required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. We are required to reimburse SPLNG for a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal, which is recorded as terminal use agreement maintenance expense on our Statements of Operations. Our portion of the cost (including affiliate) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal.

Cheniere Marketing SPA

Cheniere Marketing has entered into an SPA with us to purchase, at Cheniere Marketing’s option, any LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG.

Cheniere Marketing Master SPA

In May 2015, we entered into an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement.

Commissioning Confirmation

In May 2015, under the Cheniere Marketing Master SPA, we executed a confirmation with Cheniere Marketing that obligates Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the periods while Bechtel Oil, Gas and Chemicals, Inc. has control of, and is commissioning, the first four Trains of the Liquefaction Project.

Pre-commercial LNG Marketing Agreement

In May 2015, we entered into an agreement with Cheniere Marketing that authorizes Cheniere Marketing to act on our behalf to market and sell pre-commercial LNG that has not been accepted by BG Gulf Coast LNG, LLC, one of our SPA customers. We pay a fee to Cheniere Marketing for marketing and transportation, which is based on volume sold under this agreement.

Natural Gas Transportation Agreement

Services Agreements

Liquefaction O&M Agreement

We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project. Before the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the Liquefaction Project is operational, the services include all necessary services required to operate and maintain the Liquefaction Project. Before the Liquefaction Project is operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the Liquefaction Project is operational, we will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

of $83,333 (indexed for inflation) for services with respect to such Train. The non-reimbursement amounts incurred under this agreement are recorded in general and administrative expense—affiliate.

Liquefaction MSA

We have entered into a management services agreement (the “Liquefaction MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement. The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project. Under the Liquefaction MSA, we pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month, which is recorded as general and administrative expense—affiliate on our Statements of Operations. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train.

Cheniere Investments Information Technology Services Agreement

Cheniere Investments has entered into an information technology services agreement with Cheniere, pursuant to which Cheniere Investment’s subsidiaries, including us, receive certain information technology services. On a quarterly basis, the various entities receiving the benefit are invoiced by Cheniere according to the cost allocation percentages set forth in the agreement. In addition, Cheniere is entitled to reimbursement for all costs incurred by Cheniere that are necessary to perform the services under the agreement.

LNG Site Sublease Agreement

We have entered into agreements with SPLNG to sublease a portion of the Sabine Pass LNG terminal site for the Liquefaction Project. The aggregate annual sublease payment is $0.9 million, which was increased from $0.5 million during 2015. The initial terms of the subleases expire on December 31, 2034, with options to renew for multiple 10-year extensions with similar terms as the initial terms. The annual sublease payments will be adjusted for inflation every 5 years based on a consumer price index, as defined in the sublease agreements.

Cooperation Agreement

We have entered into an agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project. In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. Under this agreement, we conveyed to SPLNG zero and $252.8 million of assets for the three and nine months ended September 30, 2016, respectively, and zero and $80.5 million of assets for the three and nine months ended September 30, 2015, respectively, which have been recorded as non-cash distributions to affiliates.

Interconnect Agreement

We have entered into an agreement with CTPL to construct certain interconnect facilities between a 94-mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines and the Liquefaction Project, with ownership and responsibility for maintenance and operation transferred to CTPL following construction. Upon completion of certain modifications during the third quarter of 2015, we conveyed to CTPL $10.1 million of assets under this agreement.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Contract for Sale and Purchase of Natural Gas and LNG

We have entered into an agreement with SPLNG that allows us to sell and purchase natural gas and LNG with SPLNG. Natural gas and LNG purchased under this agreement are recorded as inventory, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process.

State Tax Sharing Agreement

In August 2012, we entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we 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, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were calculated on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.

NOTE 11—SUPPLEMENTAL CASH FLOW INFORMATION

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



	Nine Months Ended September 30,
	2016		2015
Cash paid during the period for interest, net of amounts capitalized	$	60,506	$	13,471
Non-cash distributions to affiliates for conveyance of assets	252,802		90,645
Other non-cash distribution to affiliates	—		149
Non-cash conveyance of assets to non-affiliate	—		13,169

The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $295.6 million and $358.3 million, as of September 30, 2016 and 2015, respectively.

NOTE 12—RECENT ACCOUNTING STANDARDS

The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of September 30, 2016:



Standard	Description	Expected Date of Adoption	Effect on our Financial Statements or Other Significant Matters
ASU 2014-09, Revenue from Contracts with Customers (Topic 606), and subsequent amendments thereto	This standard amends existing revenue recognition guidance and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance may be early adopted beginning January 1, 2017, and may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption.	January 1, 2018	We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.
ASU 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern	This standard requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. Early adoption is permitted.	December 31, 2016	The adoption of this guidance is not expected to have an impact on our Financial Statements or related disclosures.

SABINE PASS LIQUEFACTION, LLC

NOTES TO FINANCIAL STATEMENTS—CONTINUED

(unaudited)



Standard	Description	Expected Date of Adoption	Effect on our Financial Statements or Other Significant Matters
ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory	This standard requires inventory to be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance may be early adopted and must be adopted prospectively.	January 1, 2017	We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.
ASU 2016-02, Leases (Topic 842)	This standard requires a lessee to recognize leases on its balance sheet by recording a 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. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients.	January 1, 2019	We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.
ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory	This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach.	January 1, 2018	We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.

Additionally, the following table provides a brief description of a recent accounting standard that was adopted by the Company during the reporting period:


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

Information Regarding Forward-Looking Statements

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements.” All statements, other than statements of historical facts, 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 natural gas liquefaction project, 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 ability to enter into such transactions;


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


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


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


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


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


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


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


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

All of these types of statements, other than statements of historical fact, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” 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 due to factors described in this quarterly report and in the other reports and other information that we file with the SEC. These forward-looking statements speak only as of the date made, and other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

Our actual results could differ materially from those anticipated in these forward-looking statements as a result of a variety of factors, including those discussed under “Risk Factors” in our annual report on Form 10-K for the year ended December 31, 2015. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. Other than as required under the securities laws, we assume no obligation to update or revise these forward-looking statements or provide reasons why actual results may differ.

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 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


•	Liquidity and Capital Resources


•	Results of Operations


•	Off-Balance Sheet Arrangements


•	Summary of Critical Accounting Estimates


•	Recent Accounting Standards

Overview of Business

We were formed by Cheniere Partners to own, develop and operate natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities owned and operated by SPLNG. Our vision is to be recognized as the premier global LNG company and provide a reliable, competitive and integrated source of LNG to our customers while creating a safe, productive and rewarding work environment for our employees. We plan to construct up to six Trains, which are in various stages of development and construction. Trains 1 and 2 have commenced operating activities, Train 3 is undergoing commissioning, Trains 4 and 5 are under construction and Train 6 is fully permitted. Each Train is expected to have a nominal production capacity of approximately 4.5 mtpa of LNG.

Overview of Significant Events

Our significant accomplishments since January 1, 2016 and through the filing date of this Form 10-Q include the following:


•	We commenced production and shipment of LNG commissioning cargoes from Trains 1 and 2 of the Liquefaction Project in February and August 2016, respectively, and achieved substantial completion and commenced operating activities in May and September 2016, respectively.


•	In September 2016, we initiated the commissioning process for Train 3 of the Liquefaction Project.


•	In October 2016, the previously announced planned outage to improve performance of the flare systems at the Liquefaction Project, as well as to perform scheduled maintenance to Train 1 and other facilities, was completed on schedule and budget.


•	In May 2016, Jack Fusco was appointed as our Chief Executive Officer.

•

In June and September 2016, we issued 5.875% Senior Secured Notes due 2026 (the “2026 Senior Notes”) and 5.00% Senior Secured Notes due 2027 (the “2027 Senior Notes”), respectively, for aggregate principal amounts of $1.5 billion each. Net proceeds of the offerings of the 2026 Senior Notes and 2027 Senior Notes were approximately $1.3 billion and $1.4 billion, respectively, after deducting commissions, fees and expenses and incremental interest required under the respective senior notes during construction. The net proceeds were used to prepay a portion (for the 2026 Senior Notes) or all (for the 2027 Senior Notes) of the outstanding borrowings under the credit facilities we entered into in June 2015 (the “2015 Credit Facilities”). The remaining proceeds from the 2027 Senior Notes are being used to pay a portion of the capital costs in connection with the construction of Trains 1 through 5 of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2015 Credit Facilities.

Liquidity and Capital Resources

Cash and Cash Equivalents

As of September 30, 2016, we had zero cash and cash equivalents and $325.6 million of current restricted cash.

Liquefaction Facilities

Our Liquefaction Project is being developed and constructed at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. We have received authorization from the FERC to site, construct and operate Trains 1 through 6. We commenced construction of Trains 1 and 2 and the related new facilities needed to treat, liquefy, store and export natural gas in August 2012. In May 2016 and September 2016, Trains 1 and 2 achieved substantial completion, respectively. Construction of Trains 3 and 4 and the related facilities commenced in May 2013. In June 2015, we commenced construction of Train 5 and the related facilities. In October 2016, the previously announced planned outage to improve performance of the flare systems at the Liquefaction Project, as well as to perform scheduled maintenance to Train 1 and other facilities, was completed on schedule and budget.

The DOE has authorized the export of domestically produced LNG by vessel from Trains 1 through 4 of the Sabine Pass LNG terminal to FTA countries for a 30-year term, which commenced on May 15, 2016, and to non-FTA countries for a 20-year term, which commenced on June 3, 2016, in an amount up to a combined total of the equivalent of 16 mtpa (approximately 803 Bcf/yr of natural gas). The DOE further issued orders authorizing us to export domestically produced LNG by vessel from Trains 1 through 4 of the Sabine Pass LNG terminal to FTA countries for a 25-year term and non-FTA countries for a 20-year term, in an amount up to a combined total of the equivalent of approximately 203 Bcf/yr of natural gas. Additionally, the DOE issued orders authorizing us to export domestically produced LNG by vessel from Trains 5 and 6 of the Sabine Pass LNG terminal to FTA countries and non-FTA countries for a 20-year term, in an amount up to a combined total of 503.3 Bcf/yr (approximately 10 mtpa) of natural gas. A party to the proceedings requested rehearings of the orders above related to the export of 803 Bcf/yr, 203 Bcf/yr and 503.3 Bcf/yr to non-FTA countries. The DOE issued orders denying rehearing of the orders related to 803 Bcf/yr and 503.3 Bcf/yr but has not yet issued a final ruling on the rehearing request related to the 203 Bcf/yr. In July 2016, the same party petitioned the U.S. Court of Appeals for the District of Columbia Circuit to review the DOE order related to the export of 503.3 Bcf/yr to non-FTA countries and the order denying the request for rehearing of the same. The appeal is pending. In each case, the terms 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 five to 10 years from the date the order was issued. In addition, we have a 3-year makeup period with respect to each of the non-FTA orders for LNG volumes we were unable to export during the initial 20-year export period of such order. Furthermore, in January 2016, the DOE issued an order authorizing us to export domestically produced LNG by vessel from the Sabine Pass LNG terminal to FTA countries and non-FTA countries over a two-year period commencing on January 15, 2016, in an aggregate amount up to the equivalent of 600 Bcf of natural gas (however, exports to non-FTA countries under this order, when combined with exports to non-FTA countries under the orders related to Trains 1 through 4 above, may not exceed 1,006 Bcf/yr).

As of September 30, 2016, Trains 1 and 2 of the Liquefaction Project had achieved substantial completion. As of September 30, 2016, the overall project completion percentage for Trains 3 and 4 of the Liquefaction Project was approximately 91.8%. As of September 30, 2016, the overall project completion percentage for Train 5 of the Liquefaction Project was approximately 42.8% with engineering, procurement, subcontract work and construction approximately 90.8%, 62.0%, 41.9% and 4.6% complete, respectively. As of September 30, 2016, the overall project completion of each of our Trains was ahead of the contractual schedule. We produced our first LNG from Train 1 of the Liquefaction Project in February 2016 and achieved substantial completion in May 2016. We produced our first LNG from Train 2 of the Liquefaction Project in August 2016 and achieved substantial completion in September 2016. Based on our current construction schedule, Trains 3 and 4 are expected to achieve substantial completion in 2017 and Train 5 is expected to achieve substantial completion in 2019.

Customers

We have entered into six fixed price, 20-year SPAs with third parties to make available an aggregate amount of LNG that equates to approximately 19.75 mtpa of LNG, which is approximately 88% of the expected aggregate nominal production capacity of Trains 1 through 5. The obligation to make LNG available under the SPAs commences from the date of first commercial delivery for Trains 1 through 5, as specified in each SPA. Under these SPAs, the customers will purchase LNG from us for a price consisting of a fixed fee (a portion of which is subject to annual adjustment for inflation) per MMBtu of LNG plus a variable fee equal to

115% of Henry Hub per MMBtu of LNG. In certain circumstances, the customers may elect to cancel or suspend deliveries of LNG cargoes, 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. 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 commences upon the start of operations of a specified Train.

In aggregate, the fixed fee portion to be paid by the third-party SPA customers is approximately $2.9 billion annually for Trains 1 through 5, with the applicable fixed fees starting from the date of first commercial delivery from the applicable Train. These fixed fees equal approximately $411 million, $564 million, $650 million, $648 million and $588 million for each of Trains 1 through 5, respectively.

In addition, Cheniere Marketing has entered into an SPA with us to purchase, at Cheniere Marketing’s option, any LNG produced by us in excess of that required for other customers.

Natural Gas Transportation, Storage and Supply

To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, we have entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of Cheniere Partners, and third-party pipeline companies. We have entered into firm storage services agreements with third parties to assist us in managing volatility in natural gas needs for the Liquefaction Project. We have also entered into enabling agreements and long-term natural gas supply contracts with third parties in order to secure natural gas feedstock for the Liquefaction Project. As of September 30, 2016, we have secured up to approximately 1,982.0 million MMBtu of natural gas feedstock through long-term natural gas supply contracts.

Construction

We have entered into lump sum turnkey contracts with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for the engineering, procurement and construction of Trains 1 through 5, under which Bechtel charges a lump sum for all work performed and generally bears project cost risk unless certain specified events occur, in which case Bechtel may cause us to enter into a change order, or we agree with Bechtel to a change order.

The total contract prices of the EPC contract for Trains 1 and 2, the EPC contract for Trains 3 and 4 and the EPC Contract for Train 5 of the Liquefaction Project are approximately $4.1 billion, $3.9 billion and $3.0 billion, respectively, reflecting amounts incurred under change orders through September 30, 2016. Total expected capital costs for Trains 1 through 5 are estimated to be between $12.5 billion and $13.5 billion before financing costs and between $17.0 billion and $18.0 billion after financing costs, including, in each case, estimated owner’s costs and contingencies.

Final Investment Decision on Train 6

We will contemplate making a final investment decision to commence construction of Train 6 of the Liquefaction Project based upon, among other things, entering into an EPC contract, entering into acceptable commercial arrangements and obtaining adequate financing to construct the Train.

Terminal Use Agreements

We have entered into a TUA with SPLNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG, which will provide us access to additional facilities needed for us to deliver LNG to our SPA customers. We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”), continuing until at least 20 years after we deliver our first commercial cargo at the Liquefaction Project. We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA. In connection with the assignment, we, Cheniere Investments and SPLNG also entered into a terminal use rights assignment and agreement (the “TURA”) pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees required by the TUA to SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. The percentage of the TUA Fees payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the TUA Fees payable by us will increase by the amount that Cheniere Investments’ percentage decreases. In May

2016, Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was reduced from 100% to 75% and our percentage of all TUA Fees payable to SPLNG increased from zero to 25% in accordance with the TURA. Subsequently, in September 2016, upon substantial completion of Train 2 of the Liquefaction Project, Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was further reduced from 75% to 50% and our percentage of all TUA Fees payable to SPLNG was further increased from 25% to 50% in accordance with the TURA. Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA. During the three and nine months ended September 30, 2016, we recorded operating and maintenance expense—affiliate of $18.5 million and $28.8 million, respectively, for the TUA Fees and cost of sales—affiliate of $1.8 million and $2.5 million, respectively, for cargo loading services incurred under the TURA.

Capital Resources

We currently expect that our capital resources requirements with respect to Trains 1 through 5 of the Liquefaction Project will be financed through one or more of the following: borrowings, equity contributions from Cheniere Partners and cash flows under the SPAs. We believe that with the net proceeds of borrowings, available commitments under the 2015 Credit Facilities, available commitments under the Working Capital Facility (as defined below) and cash flows from operations, we will have adequate financial resources available to complete Trains 1 through 5 of the Liquefaction Project and to meet our currently anticipated capital, operating and debt service requirements. We began generating cash flows from operations from the Liquefaction Project in May 2016, when Train 1 achieved substantial completion and initiated operating activities. Additionally, during the three and nine months ended September 30, 2016, we realized offsets to LNG terminal costs of $58.7 million and $201.0 million, respectively, that were related to the sale of commissioning cargoes because these amounts were earned prior to the start of commercial operations, during the testing phase for the construction of Trains 1 and 2 of the Liquefaction Project.

Senior Secured Notes

As of September 30, 2016, we had seven series of senior secured notes outstanding:


•	$2.0 billion of 5.625% Senior Secured Notes due 2021 (the “2021 Senior Notes”);


•	$1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 Senior Notes”);


•	$1.5 billion of 5.625% Senior Secured Notes due 2023 (the “2023 Senior Notes”);


•	$2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 Senior Notes”);


•	$2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 Senior Notes” and collectively with the 2021 Senior Notes, the 2022 Senior Notes, the 2023 Senior Notes, the 2024 Senior Notes, the 2026 Senior Notes and the 2027 Senior Notes, the “Senior Notes”);


•	$1.5 billion of 2026 Senior Notes; and


•	$1.5 billion of 2027 Senior Notes.

Interest on the Senior Notes is payable semi-annually in arrears. Subject to permitted liens, the Senior Notes are secured on a first-priority basis by a security interest in all of the membership interests in us and substantially all of our assets.

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

Under the Indenture, we may not make any distributions until, among other requirements, deposits are made into debt service reserve accounts as required and a debt service coverage ratio test of 1.25:1.00 is satisfied.

The Indenture includes restrictive covenants. We may incur additional indebtedness in the future, including by issuing additional notes, and such indebtedness could be at higher interest rates and have different maturity dates and more restrictive covenants than our current outstanding indebtedness, including the Senior Notes, the 2015 Credit Facilities and the Working Capital Facility.

2015 Credit Facilities

In June 2015, we entered into the 2015 Credit Facilities with commitments aggregating $4.6 billion. The 2015 Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the Liquefaction Project. Borrowings under the 2015 Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. During 2016, in conjunction with the issuance of the 2026 Senior Notes and the 2027 Senior Notes, we prepaid outstanding borrowings and terminated commitments under the 2015 Credit Facilities for approximately $2.6 billion. These prepayments and termination of commitments resulted in a write-off of debt issuance costs associated with the 2015 Credit Facilities of $25.8 million and $51.8 million during the three and nine months ended September 30, 2016, respectively. As of September 30, 2016, we had $2.0 billion of available commitments and no outstanding borrowings under the 2015 Credit Facilities.

Loans under the 2015 Credit Facilities accrue interest at a variable rate per annum equal to, at our election, LIBOR or the base rate plus the applicable margin. The applicable margin for LIBOR loans ranges from 1.30% to 1.75%, depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter. In addition, we are required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 Credit Facilities. The 2015 Credit Facilities also require us to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment, or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 Credit Facility. The principal of the loans made under the 2015 Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the Liquefaction Project. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2015 Credit Facilities.

The 2015 Credit Facilities contain conditions precedent for borrowings, as well as customary affirmative and negative covenants. Our obligations under the 2015 Credit Facilities are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes and the Working Capital Facility.

Under the terms of the 2015 Credit Facilities, we are required to hedge not less than 65% of the variable interest rate exposure of our projected outstanding borrowings, calculated on a weighted average basis in comparison to our anticipated draw of principal. Additionally, we may not make any distributions until certain conditions have been met, including that deposits are made into debt service reserve accounts and a debt service coverage ratio test of 1.25:1.00 is satisfied.

2013 Credit Facilities

In May 2013, we entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 Credit Facilities”) to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 4 of the Liquefaction Project. In June 2015, the 2013 Credit Facilities were replaced with the 2015 Credit Facilities.

In March 2015, in conjunction with our issuance of the 2025 Senior Notes, we terminated approximately $1.8 billion of commitments under the 2013 Credit Facilities. This termination and the replacement of the 2013 Credit Facilities with the 2015 Credit Facilities in June 2015 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 Credit Facilities of $96.3 million for the nine months ended September 30, 2015.

Working Capital Facility

In September 2015, we entered into a $1.2 billion Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “Working Capital Facility”), which replaced the $325.0 million Senior Letter of Credit and Reimbursement Agreement that was entered into in April 2014. The Working Capital Facility is intended to be used for loans (“Working Capital Loans”), the issuance of letters of credit, as well as for swing line loans (“Swing Line Loans”), primarily for certain working capital requirements related to developing and placing into operation the Liquefaction Project. We may, from time to time, request increases in the commitments under the Working Capital Facility of up to $760 million and, upon the completion of the debt financing of Train 6 of the Liquefaction Project, request an incremental increase in commitments of up to an additional $390 million. As of September 30, 2016, we had $764.5 million of available commitments, $337.0 million aggregate amount of issued letters of credit and $98.5 million of loans outstanding under the Working Capital Facility. As of December 31, 2015, we

had $1.1 billion of available commitments, $135.2 million aggregate amount of issued letters of credit and $15.0 million of loans outstanding under the Working Capital Facility.

The Working Capital Facility accrues interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the senior facility agent’s published prime rate, the federal funds effective rate, as published by the Federal Reserve Bank of New York, plus 0.50% and one month LIBOR plus 0.50%), plus the applicable margin. The applicable margin for LIBOR loans under the Working Capital Facility is 1.75% per annum, and the applicable margin for base rate loans under the Working Capital Facility is 0.75% per annum. Interest on Swing Line Loans and loans deemed made in connection with a draw upon a letter of credit (“LC Loans”) is due and payable on the date the loan becomes due. Interest on LIBOR Working Capital Loans is due and payable at the end of each applicable LIBOR period, and interest on base rate Working Capital Loans is due and payable at the end of each fiscal quarter. However, if such base rate Working Capital Loan is converted into a LIBOR Working Capital Loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date.

We pay (1) a commitment fee equal to an annual rate of 0.70% on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans and (2) a letter of credit fee equal to an annual rate of 1.75% of the undrawn portion of all letters of credit issued under the Working Capital Facility. If draws are made upon a letter of credit issued under the Working Capital Facility and we do not elect for such draw (an “LC Draw”) to be deemed an LC Loan, we are required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw. An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of September 30, 2016, no LC Draws had been made upon any letters of credit issued under the Working Capital Facility.

The Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year. Swing Line Loans terminate upon the earliest of (1) the maturity date or earlier termination of the Working Capital Facility, (2) the date 15 days after such Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. We are required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. Our obligations under the Working Capital Facility are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes and the 2015 Credit Facilities.

Sources and Uses of Cash

The following table (in thousands) summarizes the sources and uses of our cash, cash equivalents and restricted cash for the nine months ended September 30, 2016 and 2015. 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.



	Nine Months Ended September 30,
	2016			2015
Operating cash flows
Net cash provided by (used in) operating activities	$	—		$	—
Changes in restricted cash for certain operating activities	(157,291		)	(230,187		)
Cash, cash equivalents and restricted cash used in operating activities	(157,291		)	(230,187		)

Investing cash flows
Net cash provided by (used in) investing activities	—			—
Use of restricted cash for the acquisition of property, plant and equipment	(1,905,102		)	(2,144,821		)
Cash, cash equivalents and restricted cash used in investing activities	(1,905,102		)	(2,144,821		)

Financing cash flows
Net cash provided by (used in) financing activities	—			—
Investment in restricted cash	2,198,763			2,089,295
Cash, cash equivalents and restricted cash provided by financing activities	2,198,763			2,089,295

Net increase (decrease) in cash, cash equivalents and restricted cash	136,370			(285,713		)
Cash, cash equivalents and restricted cash—beginning of period	189,260			612,863
Cash, cash equivalents and restricted cash—end of period	$	325,630		$	327,150

Operating Cash Flows

Operating cash flows during the nine months ended September 30, 2016 and 2015 were $157.3 million and $230.2 million, respectively. The decrease in operating cash outflows in 2016 compared to 2015 primarily related to increased cash receipts from the sale of LNG cargoes, partially offset by increased operating costs and expenses as a result of the commencement of operations of Trains 1 and 2 of the Liquefaction Project in May and September 2016, respectively.

Investing Cash Flows

Investing cash flows during the nine months ended September 30, 2016 and 2015 were $1.9 billion and $2.1 billion, respectively, and were primarily used to fund the construction costs for Trains 1 through 5 of the Liquefaction Project. These costs are capitalized as construction-in-process until achievement of substantial completion. Additionally, during the nine months ended September 30, 2016 and 2015, we used $32.1 million and $50.3 million, respectively, primarily to pay a municipal water district for water system enhancements that will increase potable water supply to the Sabine Pass LNG terminal and payments made pursuant to the information technology services agreement for capital assets purchased on our behalf.

Financing Cash Flows

Financing cash flows during the nine months ended September 30, 2016 were $2.2 billion, primarily as a result of:


•	$1.7 billion of borrowings under the 2015 Credit Facilities;


•	issuance of an aggregate principal amount of $1.5 billion of the 2026 Senior Notes in June 2016, which was used to prepay $1.3 billion of the outstanding borrowings under the 2015 Credit Facilities;


•	issuance of an aggregate principal amount of $1.5 billion of the 2027 Senior Notes in September 2016, which was used to prepay $1.2 billion of the outstanding borrowings under the 2015 Credit Facilities and pay a portion of the capital costs in connection with the construction of Trains 1 through 5 of the Liquefaction Project;


•	$313.5 million of borrowings and a $230.0 million repayment made under the Working Capital Facility;


•	$40.7 million of debt issuance costs related to up-front fees paid upon the closing of these transactions; and


•	$1.3 million of equity contributions from Cheniere Partners, which decreased compared to the contributions received in the nine months ended September 30, 2015, as a result of utilizing our borrowings instead of equity contributions from Cheniere Partners to finance our capital resource requirements.

Financing cash flows during the nine months ended September 30, 2015 were $2.1 billion, primarily as a result of:


•	issuance of an aggregate principal amount of $2.0 billion of the 2025 Senior Notes in March 2015;


•	entering into the 2015 Credit Facilities June 2015 and borrowing $250.0 million under this facility during the nine months ended September 30, 2015;


•	$176.0 million of debt issuance and deferred financing costs related to up-front fees paid upon the closing of these transactions; and


•	$15.3 million of equity contributions from Cheniere Partners.

Results of Operations

Our net loss was $104.3 million in the three months ended September 30, 2016, compared to a net loss of $12.8 million in the three months ended September 30, 2015. This $91.5 million increase in net loss in 2016 was primarily a result of increased interest expense, net of amounts capitalized, loss from operations and loss on early extinguishment of debt, which was partially offset by decreased derivative loss, net.

Our net loss was $238.3 million in the nine months ended September 30, 2016, compared to a net loss of $230.5 million in the nine months ended September 30, 2015. This $7.8 million increase in net loss in 2016 was primarily a result of increased interest expense, net of amounts capitalized, and loss from operations, which was partially offset by decreased loss on early extinguishment of debt and derivative loss, net.

Revenues



	Three Months Ended September 30,						Nine Months Ended September 30,
(in thousands)	2016		2015		Change		2016		2015		Change
LNG revenues	$	248,188	$	—	$	248,188	$	333,542	$	—	$	333,542
LNG revenues—affiliate	16,236		—		16,236		16,236		—		16,236
Total revenues	$	264,424	$	—	$	264,424	$	349,778	$	—	$	349,778

We began recognizing LNG revenues from the Liquefaction Project following the substantial completion of Trains 1 and 2 in May and September 2016, respectively. Prior to these dates, amounts received from the sale of commissioning cargoes were offset against LNG terminal construction-in-process because these amounts were earned during the testing phase for the construction of those Trains of the Liquefaction Project. During the three and nine months ended September 30, 2016, we loaded a total of 60.3 million MMBtu and 113.8 million MMBtu of LNG, respectively, of which 50.8 million MMBtu and 69.0 million MMBtu, respectively, resulted in the recognition of revenues related to this volume. The remaining 9.5 million MMBtu and 44.8 million MMBtu of LNG loaded during the three and nine months ended September 30, 2016, respectively, were recognized as offsets to LNG terminal costs as they related to the sale of commissioning cargoes.

Operating costs and expenses



	Three Months Ended September 30,								Nine Months Ended September 30,
(in thousands)	2016		2015			Change			2016			2015			Change
Cost (cost recovery) of sales	$	161,829	$	(32,106	)	$	193,935		$	217,567		$	(32,176	)	$	249,743
Cost of sales—affiliate	3,245		—			3,245			3,890			—			3,890
Operating and maintenance expense	24,588		1,623			22,965			40,606			4,655			35,951
Operating and maintenance expense—affiliate	43,468		328			43,140			66,230			456			65,774
Terminal use agreement maintenance expense (recovery)	72		(837		)	909			(546		)	16,684			(17,230		)
Terminal use agreement maintenance expense—affiliate	—		130			(130		)	208			308			(100		)
Development expense	1		113			(112		)	137			2,631			(2,494		)
Development expense—affiliate	87		152			(65		)	484			562			(78		)
General and administrative expense	1,818		1,307			511			5,472			4,027			1,445
General and administrative expense—affiliate	18,942		18,938			4			51,824			58,304			(6,480		)
Depreciation and amortization expense	25,749		461			25,288			37,863			1,279			36,584
Total operating costs and expenses	$	279,799	$	(9,891	)	$	289,690		$	423,735		$	56,730		$	367,005

Our total operating costs and expenses increased $289.7 million and $367.0 million during the three and nine months ended September 30, 2016 compared to the three and nine months ended September 30, 2015, respectively, primarily as a result of the commencement of operations of Trains 1 and 2 of the Liquefaction Project in May and September 2016, respectively, compared to a significant cost recovery recorded during the three and nine months ended September 30, 2015. This cost recovery was due to a $32.2 million increase in fair value for our natural gas supply contracts recorded for the period, which we recognized following the completion and placement into service of certain modifications to the underlying pipeline infrastructure and the resulting development of a market for physical gas delivery at locations specified in a portion of our natural gas supply contracts. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project, and other related costs to convert natural gas into LNG, all to the extent not utilized for the commissioning process. Operating and maintenance expense includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Depreciation and amortization expense increased during the three and nine months ended September 30, 2016 as we began depreciation of our assets related to Trains 1 and 2 of the Liquefaction Project upon reaching substantial completion.

Offsetting the increases above was a decrease to terminal use agreement maintenance expense of $17.2 million in the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. This decrease was primarily as a result of not needing to import a cargo necessary to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal during the nine months ended September 30, 2016. During the nine months ended September 30, 2015, we incurred our proportionate share of the costs of the cargo imported in order to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal, which we are required to reimburse pursuant to our TUA with SPLNG.

General and administrative expense—affiliate decreased $6.5 million in the nine months ended September 30, 2016 compared to the nine months ended September 30, 2015. This decrease was primarily a result of reallocation of resources from general and administrative activities to operating and maintenance activities following commencement of operations at the Liquefaction Project.

Other expense (income)



	Three Months Ended September 30,									Nine Months Ended September 30,
(in thousands)	2016			2015			Change			2016			2015			Change
Interest expense, net of capitalized interest	$	65,939		$	11,952		$	53,987		$	99,203		$	31,261		$	67,942
Loss on early extinguishment of debt	25,765			—			25,765			52,070			96,273			(44,203		)
Derivative loss (gain), net	(2,557		)	10,872			(13,429		)	13,473			46,541			(33,068		)
Other income	(179		)	(98		)	(81		)	(430		)	(320		)	(110		)
Total other expense	$	88,968		$	22,726		$	66,242		$	164,316		$	173,755		$	(9,439	)

Interest expense, net of capitalized interest, increased $54.0 million and $67.9 million during the three and nine months ended September 30, 2016 compared to the three and nine months ended September 30, 2015, respectively, due to an increase in our indebtedness outstanding (before premium and unamortized debt issuance costs), from $8.8 billion as of September 30, 2015 to $11.6 billion as of September 30, 2016, and the decrease in the portion of total interest costs that could be capitalized as Trains 1 and 2 of the Liquefaction Project are no longer in construction. For the three and nine months ended September 30, 2016, we incurred $168.2 million and $469.5 million of total interest cost, respectively, of which we capitalized $102.3 million and $370.3 million, respectively. For the three and nine months ended September 30, 2015, we incurred $141.1 million and $388.0 million of total interest cost, respectively, of which we capitalized $129.1 million and $356.7 million, respectively.

Loss on early extinguishment of debt increased by $25.8 million in the three months ended September 30, 2016, as compared to the three months ended September 30, 2015, whereas it decreased $44.2 million in the nine months ended September 30, 2016, as compared to the nine months ended September 30, 2015. Loss on early extinguishment of debt during the three months ended September 30, 2016 was attributable to a $25.8 million write-off of debt issuance costs related to the prepayment of outstanding borrowings and termination of commitments under the 2015 Credit Facilities of approximately $1.4 billion in September 2016 in connection with the issuance of the 2027 Senior Notes. Loss on early extinguishment of debt during the nine months ended September 30, 2016 further included a $26.0 million write-off of debt issuance costs related to the prepayment of approximately $1.3 billion of outstanding borrowings under the 2015 Credit Facilities in June 2016 in connection with the issuance of the 2026 Senior Notes. Loss on early extinguishment of debt during the nine months ended September 30, 2015 was attributable to a $7.3 million write-off of debt issuance costs and deferred commitment fees related to the termination and replacement of the 2013 Credit Facilities with the 2015 Credit Facilities in June 2015 and a $89.0 million write-off of debt issuance costs and deferred commitment fees related to the termination of approximately $1.8 billion of commitments under the 2013 Credit Facilities in March 2015.

Derivative loss (gain), net decreased $13.4 million from a loss of $10.9 million in the three months ended September 30, 2015 to a gain of $2.6 million in the three months ended September 30, 2016, primarily due to a relative increase in the forward LIBOR curve in the three months ended September 30, 2016 as compared to the three months ended September 30, 2015. Derivative loss, net decreased by $33.1 million in the nine months ended September 30, 2016, as compared to the nine months ended September 30, 2015, primarily due to the $34.7 million loss recognized in March 2015 upon the termination of interest rate swaps associated with the 2013 Credit Facilities.

Off-Balance Sheet Arrangements

As of September 30, 2016, we had no transactions that met the definition of off-balance sheet arrangements that may have a current or future material effect on our financial position or operating results.

Summary of Critical Accounting Estimates

The preparation of our Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the 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 year ended December 31, 2015.

Recent Accounting Standards

For descriptions of recently issued accounting standards, see Note 12—Recent Accounting Standards of our Notes to Financial Statements.


ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Marketing and Trading Commodity Price Risk

We have entered into commodity derivatives consisting of natural gas supply contracts to secure natural gas feedstock for the Liquefaction Project (“Liquefaction Supply Derivatives”). In order to test the sensitivity of the fair value of our Liquefaction Supply Derivatives to changes in underlying commodity prices, management modeled a 10% change in the basis price for natural gas for each delivery location. As of September 30, 2016, we estimated the fair value of our Liquefaction Supply Derivatives to be $12.1 million. Based on actual derivative contractual volumes, a 10% increase or decrease in the underlying basis prices would have resulted in a change in the fair value of our Liquefaction Supply Derivatives of $0.2 million as of September 30, 2016, compared to $0.9 million as of December 31, 2015. See Note 6—Derivative Instruments for additional details about our derivative instruments.

Interest Rate Risk

We have entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under our 2015 Credit Facilities (“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 1-month LIBOR curve across the remaining term of the Interest Rate Derivatives. As of September 30, 2016, we estimated the fair value of the Interest Rate Derivatives to be a liability of $15.9 million. This 10% change in interest rates would have resulted in a change in the fair value of our Interest Rate Derivatives of $1.6 million as of September 30, 2016, compared to $3.1 million as of December 31, 2015. The decrease in the effect of change in interest rates was due to a decrease in the forward 1-month LIBOR curve during the nine months ended September 30, 2016.


ITEM 4.	CONTROLS AND PROCEDURES

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

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


PART II.	OTHER INFORMATION


ITEM 1.	LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters.

Please see Part II, Item 1, “Legal Proceedings - LDEQ Matter” in the Company’s Quarterly Report on Form 10-Q for the period ended March 31, 2016.


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 year ended December 31, 2015.


ITEM 5.	OTHER INFORMATION

Compliance Disclosure

Pursuant to Section 13(r) of the Exchange Act, if during the quarter ended September 30, 2016, we or any of our affiliates had engaged in certain transactions with Iran or with persons or entities designated under certain executive orders, we would be required to disclose information regarding such transactions in our quarterly report on Form 10-Q as required under Section 219 of the Iran Threat Reduction and Syria Human Rights Act of 2012. During the quarter ended September 30, 2016, we did not engage in any transactions with Iran or with persons or entities related to Iran.


ITEM 6.	EXHIBITS



Exhibit No.		Description
4.1		Eighth Supplemental Indenture, dated as of September 19, 2016, between Sabine Pass Liquefaction, LLC and The Bank of New York Mellon, as Trustee under the Indenture (Incorporated by reference to Exhibit 4.1 to Cheniere Partners’ Current Report on Form 8-K (SEC File No. 001-33366), filed on September 23, 2016)
4.2		Ninth Supplemental Indenture, dated as of September 23 2016, between Sabine Pass Liquefaction, LLC and The Bank of New York Mellon, as Trustee under the Indenture (Incorporated by reference to Exhibit 4.2 to Cheniere Partners’ Current Report on Form 8-K (SEC File No. 001-33366), filed on September 23, 2016)
10.1*		Change orders to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Liquefaction Facility, dated as of November 11, 2011, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: (i) the Change Order CO-00048 N2 Supply for High Pressure Tightness Test During Commissioning and Startup, dated July 12, 2016, (ii) the Change Order CO-00050 Train 2 N2 Dryout, dated July 29, 2016, (iii) the Change Order CO-00051 Six-Day Work Week for Insulation Scope — Subproject 2, dated August 9, 2016, and (iv) the Change Order CO-00052 Process Flares Modification Provisional Sum, dated September 1, 2016 (Portions of this exhibit have been omitted and filed separately with the SEC pursuant to a request for confidential treatment.)
10.2*		Change orders to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 2 Liquefaction Facility, dated as of December 20, 2012, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: (i) the Change Order CO-00024 Additional Support for FERC Document Requests, dated June 20, 2016, (ii) the Change Order CO-00025 N2 Supply for High Pressure Tightness Test During Commissioning and Startup, dated July 12, 2016, (iii) the Change Order CO-00027 Addition of Check Valves to Condensate Lines, dated July 29, 2016, (iv) the Change Order CO-00028 Additional Professional Services Support Hours for the Flare System Evaluation, dated August 3, 2016, and (v) the Change Order CO-00029 Lump Sum Process Flares Modification, dated September 1, 2016 (Portions of this exhibit have been omitted and filed separately with the SEC pursuant to a request for confidential treatment.)
10.3*		Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 3 Liquefaction Facility, dated as of May 4, 2015, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: the Change Order CO-00011 Site Drainage Design Change: Professional Service Hours, dated July 26, 2016
10.4		Registration Rights Agreement, dated as of September 23, 2016, between Sabine Pass Liquefaction, LLC and Merrill Lynch, Pierce, Fenner & Smith Incorporated (Incorporated by reference to Exhibit 10.1 to Cheniere Partners’ Current Report on Form 8-K (SEC File No. 001-33366), filed on September 23, 2016)
31.1*		Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
31.2*		Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**		Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**		Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*		XBRL Instance Document
101.SCH*		XBRL Taxonomy Extension Schema Document
101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*		XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document



*	Filed herewith.
**	Furnished herewith.

SIGNATURES

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



		SABINE PASS LIQUEFACTION, LLC

Date:	November 2, 2016	By:	/s/ Michael J. Wortley
			Michael J. Wortley
			Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)

Date:	November 2, 2016	By:	/s/ Leonard Travis
			Leonard Travis
			Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

Description

Date of Adoption

Effect on our Financial Statements or Other Significant Matters

ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements

These standards require debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. Debt issuance costs incurred in connection with line of credit arrangements may be presented as an asset and subsequently amortized ratably over the term of the line of credit arrangement. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented.

January 1, 2016

Upon adoption of these standards, the balance of debt, net was reduced by the balance of debt issuance costs, net, except for the balance related to line of credit arrangements, on our Balance Sheets. See Note 9—Debt for additional disclosures.