Sabine Pass LNG 10-Q 2015 Q1 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549FORM 10-Q

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

For the quarterly period ended March 31, 2015

OR

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

For the transition period fromto

Commission File No. 333-138916

 Sabine Pass LNG, L.P.

(Exact name of registrant as specified in its charter)

Delaware	20-0466069
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
700 Milam Street, Suite 1900 Houston, Texas	77002
(Address of principal executive offices)	(Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

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  x    No  ¨

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 LNG, L.P.

TABLE OF CONTENTS

	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	2
	Consolidated Balance Sheets	2
	Consolidated Statements of Income	3
	Consolidated Statement of Partners’ Deficit	4
	Consolidated Statements of Cash Flows	5
	Notes to Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	13
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	17
Item 4.	Controls and Procedures	17
Part II. Other Information
Item 1.	Legal Proceedings	18
Item 1A.	Risk Factors	18
Item 5.	Other Information	18
Item 6.	Exhibits	19
	Signatures	20

i

DEFINITIONS

As commonly used in the liquefied natural gas industry, to the extent applicable, and as used in this quarterly report, the following terms have the following meanings: 

Common Industry and Other Terms

Bcf/d	billion cubic feet per day
Bcfe	billion cubic feet equivalent
GAAP	generally accepted accounting principles in the United States
LNG	liquefied natural gas, a product of natural gas consisting primarily of methane (CH4) that is in liquid form at near atmospheric pressure
Train	a compressor train used in the industrial process to convert natural gas into LNG
TUA	terminal use agreement

Company Abbreviations

Cheniere	Cheniere Energy, Inc.
Cheniere Marketing	Cheniere Marketing, LLC
Cheniere Partners	Cheniere Energy Partners, L.P.
Cheniere Investments	Cheniere Energy Investments, LLC
Cheniere Terminals	Cheniere LNG Terminals, LLC
Tug Services	Sabine Pass Tug Services, LLC
SPL	Sabine Pass Liquefaction, LLC

Unless the context requires otherwise, references to “Sabine Pass LNG,” “we,” “us” and “our” refer to Sabine Pass LNG, L.P. and its wholly owned subsidiary.

1

PART I.        FINANCIAL INFORMATION 

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands)

	March 31,			December 31,
	2015			2014
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	7,665		$	5,460
Restricted cash and cash equivalents	53,013			14,959
Accounts receivable	25,896			—
Accounts receivable—affiliate	28,233			1,055
Advances to affiliate	6,415			1,868
LNG inventory	15,659			1,987
Prepaid expenses and other	4,800			4,301
Total current assets	141,681			29,630
Non-current restricted cash and cash equivalents	76,106			76,106
Property, plant and equipment, net	1,381,835			1,392,443
Debt issuance costs, net	11,601			12,643
Other non-current assets	22,244			19,802
Total assets	$	1,633,467		$	1,530,624
LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities
Accounts payable	$	3,271		$	408
Accrued liabilities	62,364			16,036
Due to affiliates	9,214			2,266
Deferred revenue	26,653			26,655
Deferred revenue—affiliate	21,836			21,839
Total current liabilities	123,338			67,204
Long-term debt, net of discount	2,077,676			2,076,502
Non-current deferred revenue	12,500			13,500
Non-current deferred revenue—affiliate	22,080			19,626
Other non-current liabilities	258			263
Commitments and contingencies
Partners’ deficit	(602,385		)	(646,471		)
Total liabilities and partners’ deficit	$	1,633,467		$	1,530,624

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

2

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

(in thousands)

(unaudited)

	Three Months Ended
	March 31,
	2015			2014
Revenues
Revenues	$	66,718		$	66,410
Revenues—affiliates	64,128			64,324
Total revenues	130,846			130,734
Operating costs and expenses
Operating and maintenance expense	11,248			9,316
Operating and maintenance expense—affiliate	3,644			3,693
Depreciation expense	10,603			10,615
General and administrative expense	628			(11		)
General and administrative expense—affiliate	2,771			2,826
Total operating costs and expenses	28,894			26,439
Income from operations	101,952			104,295
Other income (expense)
Interest expense	(40,269		)	(40,270		)
Derivative gain, net	55			242
Other income	8			4
Total other expense	(40,206		)	(40,024		)
Net income	$	61,746		$	64,271

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

3

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF PARTNERS’ DEFICIT

(in thousands)

(unaudited)

	General Partner Sabine Pass LNG-GP, LLC		Limited Partner Sabine Pass LNG-LP, LLC			Total Partners’ Deficit
Balance at December 31, 2014	$	—	$	(646,471	)	$	(646,471	)
Net income	—		61,746			61,746
Capital contributions from Cheniere Partners	—		53,122			53,122
Distributions to limited partner	—		(70,782		)	(70,782		)
Balance at March 31, 2015	$	—	$	(602,385	)	$	(602,385	)

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

4

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Three Months Ended
	March 31,
	2015			2014
Cash flows from operating activities
Net income	$	61,746		$	64,271
Adjustments to reconcile net income to net cash provided by operating activities:
Investment in restricted cash and cash equivalents for certain operating activities	(38,053		)	(38,054		)
Depreciation expense	10,603			10,615
Amortization of debt issuance costs and discount	2,216			2,217
Other	770			10
Changes in operating assets and liabilities:
Accounts payable and accrued liabilities	49,188			39,011
Due to affiliates	6,949			(11,016		)
Deferred revenue	(1,003		)	(871		)
Deferred revenue—affiliate	(3		)	86
Advances to affiliate	(4,546		)	(2,782		)
Accounts receivable	(25,901		)	(138		)
Accounts receivable—affiliate	(27,179		)	395
LNG inventory	(14,449		)	—
Other, net	(2,928		)	(978		)
Other—affiliate	2,451			—
Net cash provided by operating activities	19,861			62,766
Cash flows from investing activities
Property, plant and equipment, net	4			(8		)
Net cash provided by (used in) investing activities	4			(8		)
Cash flows from financing activities
Distributions to limited partner	(70,782		)	(63,437		)
Capital contributions from Cheniere Partners	53,122			—
Net cash used in financing activities	(17,660		)	(63,437		)
Net increase (decrease) in cash and cash equivalents	2,205			(679		)
Cash and cash equivalents—beginning of period	5,460			14,994
Cash and cash equivalents—end of period	$	7,665		$	14,315

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

5

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—BASIS OF PRESENTATION

The accompanying unaudited Consolidated Financial Statements of Sabine Pass LNG 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 consolidated financial position, results of operations or cash flows.

Results of operations for the three months ended March 31, 2015 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2015.

We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Income, 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 Consolidated Financial Statements.

For further information, refer to the consolidated financial statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2014.

NOTE 2—RESTRICTED CASH AND CASH EQUIVALENTS

Restricted cash and cash equivalents consist of funds that are contractually restricted as to usage or withdrawal, are controlled by a collateral trustee and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets.

We have consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of 7.50% Senior Secured Notes due 2016 (the “2016 Senior Notes”) and $420.0 million of 6.50% Senior Secured Notes due 2020 (the “2020 Senior Notes”). Collectively, the 2016 Senior Notes and the 2020 Senior Notes are referred to as the “Senior Notes.” Under the indentures governing the Senior Notes (the “Senior Notes Indentures”), except for permitted tax distributions, we may not make distributions until certain conditions are satisfied, including: (i) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (ii) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Senior Notes Indentures.

As of March 31, 2015 and December 31, 2014, we classified $53.0 million and $15.0 million, respectively, as current restricted cash and cash equivalents for the payment of current interest due. As of both March 31, 2015 and December 31, 2014, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash and cash equivalents.

See Note 6—Long-Term Debt for additional details about our long-term debt.

6

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 3—PROPERTY, PLANT AND EQUIPMENT

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

	March 31,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	1,643,020		$	1,643,018
LNG terminal construction-in-process	21			27
LNG site and related costs, net	140			142
Accumulated depreciation	(261,514		)	(250,954		)
Total LNG terminal costs, net	1,381,667			1,392,233
Fixed assets
Machinery and equipment	1,169			1,169
Computer and office equipment	424			424
Vehicles	654			654
Other	697			697
Accumulated depreciation	(2,776		)	(2,734		)
Total fixed assets, net	168			210
Property, plant and equipment, net	$	1,381,835		$	1,392,443

NOTE 4—DERIVATIVE INSTRUMENTS

During the second quarter of 2013, we began to enter into forward contracts under an International Swaps and Derivatives Association master agreement with Cheniere Marketing, a wholly owned subsidiary of Cheniere, to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate our LNG terminal (“Fuel Derivatives”). We elected to account for these Fuel Derivatives as normal purchase normal sale transactions, exempt from fair value accounting. Gains and losses for these physical hedges are not reflected on our Consolidated Statements of Income until the period of delivery. We had not posted collateral with Cheniere Marketing for such forward contracts as of March 31, 2015 and December 31, 2014.

Additionally, we have entered into certain derivative instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory (“LNG Inventory Derivatives”).

The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014, which are classified as prepaid expenses and other in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	March 31, 2015								December 31, 2014
	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
LNG Inventory Derivatives asset	$	—	$	20	$	—	$	20	$	—	$	145	$	—	$	145

The estimated fair values of our LNG Inventory 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. Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all our 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 where our LNG Inventory Derivatives are in an asset position. Our derivative transactions 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 these derivative activities. We had collateral calls of $9,000 and $0.1 million for such contracts, which have

7

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

not been reflected in the derivative fair value tables, but are included in the other current assets balance as of March 31, 2015 and December 31, 2014, respectively.

We recognize all derivative instruments that qualify for derivative accounting treatment as either assets or liabilities and measure those instruments at fair value.

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

		Fair Value Measurements as of
	Balance Sheet Location	March 31, 2015		December 31, 2014
LNG Inventory Derivatives asset	Prepaid expenses and other	$	20	$	145

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain, net on our Consolidated Statements of Income during the three months ended March 31, 2015 and 2014:

	Three Months Ended March 31,
	2015		2014
LNG Inventory Derivatives gain	$	55	$	—
Fuel Derivatives gain (1)	—		242

(1) Fuel Derivatives gain for the three months ended March 31, 2014 represents the changes in the fair value and settlements of certain Fuel Derivatives that were previously not elected to be accounted under the normal purchase normal sale exception from derivative accounting. During the three months ended March 31, 2015, all settlements of Fuel Derivatives were recorded as operating and maintenance expense, as the normal purchase normal sale exception was elected for all Fuel Derivatives outstanding.

Balance Sheet Presentation

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

	Gross Amounts Recognized		Gross Amounts Offset in the Consolidated Balance Sheets		Net Amounts Presented in the Consolidated Balance Sheets
Offsetting Derivative Assets (Liabilities)
As of March 31, 2015:
LNG Inventory Derivatives	$	20	$	—	$	20
As of December 31, 2014:
LNG Inventory Derivatives	145		132		13

NOTE 5—ACCRUED LIABILITIES

As of March 31, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands): 

	March 31,		December 31,
	2015		2014
Interest expense and related debt fees	$	53,012	$	14,959
LNG terminal costs	9,352		1,077
Total accrued liabilities	$	62,364	$	16,036

8

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 6—LONG-TERM DEBT

As of March 31, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands):

	March 31,			December 31,
	2015			2014
Long-term debt
2016 Senior Notes	$	1,665,500		$	1,665,500
2020 Senior Notes	420,000			420,000
Total long-term debt	2,085,500			2,085,500
Long-term debt discount
2016 Senior Notes	(7,824		)	(8,998		)
Total long-term debt, net	$	2,077,676		$	2,076,502

Senior Notes

As of both March 31, 2015 and December 31, 2014, we had an aggregate principal amount of $1,665.5 million, before discount, of the 2016 Senior Notes and $420.0 million of the 2020 Senior Notes outstanding. Borrowings under the 2016 Senior Notes and 2020 Senior Notes accrue interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Senior Notes and 2020 Senior Notes are substantially similar. 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 our equity interests and substantially all of our operating assets.

We may redeem all or part of our 2016 Senior Notes at any time, and from time to time, at a redemption price equal to 100% of the principal plus any accrued and unpaid interest plus the greater of:

• 1.0% of the principal amount of the 2016 Senior Notes; or

• the excess of: (a) the present value at such redemption date of (i) the redemption price of the 2016 Senior Notes plus (ii) all required interest payments due on the 2016 Senior Notes (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the treasury rate as of such redemption date plus 50 basis points; over (b) the principal amount of the 2016 Senior Notes, if greater.

We may redeem all or part of our 2020Senior Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. We may also, at our option, redeem all or part of the 2020Senior Notes at any time prior to November 1, 2016, at a “make-whole” price set forth in the indenture governing the 2020Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, we may redeem up to 35% of the aggregate principal amount of the 2020Senior Notes at a redemption price of 106.5% of the principal amount of the 2020Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the redemption date, in an amount not to exceed the net proceeds of one or more completed equity offerings as long as we redeem the 2020Senior Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Senior Notes originally issued remains outstanding after the redemption.

Under the Senior Notes Indentures, except for permitted tax distributions, we may not make distributions until certain conditions are satisfied as described in Note 2—Restricted Cash and Cash Equivalents. During the three months ended March 31, 2015 and 2014, we made distributions of $70.8 million and $63.4 million, respectively, after satisfying all the applicable conditions in the Senior Notes Indentures.

9

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Fair Value Disclosures

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

	March 31, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value (1)		Carrying Amount		Estimated Fair Value (1)
2016 Senior Notes, net of discount	$	1,657,676	$	1,757,136	$	1,656,502	$	1,718,621
2020 Senior Notes	420,000		428,400		420,000		428,400

(1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on March 31, 2015 and December 31, 2014, as applicable.

NOTE 7—RELATED PARTY TRANSACTIONS

Terminal Use Agreement

SPL, a wholly owned subsidiary of Cheniere Partners, obtained approximately 2.0 Bcf/d of regasification capacity under a TUA with us as a result of an assignment in July 2012 by Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, of its rights, title and interest under its TUA with us. SPL is obligated to make monthly capacity payments to us aggregating approximately $250 million per year, continuing until at least 20 years after SPL delivers its first commercial cargo at SPL’s facilities under construction. We entered into a terminal use rights assignment and agreement (“TURA”) with SPL and Cheniere Investments pursuant to which Cheniere Investments has the right to use SPL’s reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to us. Cheniere Investments’ right to use capacity at our LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operations. The percentage of the monthly capacity payments 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 monthly capacity payments payable by SPLwill increase by the amount that Cheniere Investments’ percentage decreases. Cheniere Partners has guaranteed SPL’s obligations under the TUA and the obligations of Cheniere Investments under the TURA.

Services Agreements

We have entered into a long-term operation and maintenance agreement (the “O&M Agreement”) with Cheniere Investments pursuant to which we receive all necessary services required to operate and maintain our LNG receiving terminal. Cheniere Investments provides the services required under the O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. We are required to pay a fixed monthly fee of $130,000 (indexed for inflation) under the O&M Agreement (the “O&M Fees”), and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between us and the counterparty at the beginning of each operating year. In addition, we are required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses. Cheniere Investments provides the services required under the Sabine Pass LNG O&M Agreement pursuant to a secondment agreement with a wholly owned subsidiary of Cheniere. 

We have entered into a long-term management services agreement (the “MSA”) with Cheniere Terminals, a wholly owned subsidiary of Cheniere, pursuant to which Cheniere Terminals manages the operation of our LNG receiving terminal, excluding those matters provided for under the O&M Agreement. We are required to pay Cheniere Terminals a monthly fixed fee of $520,000 (indexed for inflation) under the MSA. 

As of March 31, 2015 and December 31, 2014, we had $6.4 million and $1.9 million, respectively, of advances to affiliates under the foregoing services agreements. During each of the three months ended March 31, 2015 and 2014, we recorded general and administrative expense—affiliate of $2.8 million and operating and maintenance expense—affiliate of $3.8 million under the foregoing services agreements.

Agreement to Fund Our Cooperative Endeavor Agreements (“CEAs”)

In July 2007, we executed CEAs with various Cameron Parish, Louisiana taxing authorities that allow them to collect certain annual property tax payments in 2007 through 2016. This 10-year initiative represents an aggregate commitment of up to $25.0

10

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

million, and we will make resources available to the Cameron Parish taxing authorities on an accelerated basis in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for our advance payments of annual ad valorem taxes, Cameron Parish will grant us a dollar-for-dollar credit against future ad valorem taxes to be levied against our LNG terminal starting in 2019. In September 2007, we entered into an agreement with Cheniere Marketing, pursuant to which Cheniere Marketing would pay us additional TUA revenues equal to any and all amounts payable under the CEAs in exchange for a similar amount of credits against future TUA payments it would owe us under its TUA starting in 2019. In June 2010, Cheniere Marketing assigned its TUA to Cheniere Investments and concurrently entered into a variable capacity rights agreement (“VCRA”), allowing Cheniere Marketing to utilize Cheniere Investments’ capacity under the TUA after the assignment. In July 2012, Cheniere Investments entered into an amended and restated VCRA with Cheniere Marketing in order for Cheniere Investments to utilize during construction of SPL’s liquefaction project the capacity rights granted under the TURA. Cheniere Marketing will continue to fund the CEAs during the term of the amended and restated VCRA and, in exchange, Cheniere Marketing will receive the benefit of any future credits.

These advance tax payments were recorded to other non-current assets, and payments from Cheniere Marketing that we utilized to make the ad valorem tax payments were recorded as deferred revenue—affiliate. As of March 31, 2015 and December 31, 2014, we had $22.1 million and $19.6 million, respectively, of other non-current assets resulting from ad valorem tax payments and non-current deferred revenue—affiliate resulting from these payments received from Cheniere Marketing.

Contracts for Sale and Purchase of Natural Gas and LNG

We are able to sell and purchase natural gas and LNG under agreements with Cheniere Marketing. Under these agreements, we purchase natural gas or LNG from Cheniere Marketing at a sales price equal to the actual purchase cost paid by Cheniere Marketing to suppliers of the natural gas or LNG, plus any third-party costs incurred by Cheniere Marketing in respect of the receipt, purchase and delivery of the natural gas or LNG to our LNG terminal. As a result, we record the purchases of natural gas and LNG from Cheniere Marketing to be utilized as fuel to operate our LNG terminal as operating and maintenance expense. We recorded $1.6 million and $0.5 million of natural gas purchased from Cheniere Marketing under these agreements as operating and maintenance expense in the three months ended March 31, 2015 and 2014, respectively. We recorded revenues of $1.3 million and zero for natural gas sold to Cheniere Marketing under these agreements in the three months ended March 31, 2015 and 2014, respectively.

Tug Boat Lease Sharing Agreement

In connection with our tug boat lease, Tug Services, our wholly owned subsidiary, entered into a tug sharing agreement with a wholly owned subsidiary of Cheniere to provide its LNG cargo vessels with tug boat and marine services at our LNG terminal. Tug Services recorded revenues—affiliate of $0.7 million pursuant to this agreement in each of the three months ended March 31, 2015 and 2014.

LNG Site Sublease Agreement

In June 2012, we entered into an agreement with SPL to sublease a portion of our LNG terminal site for its liquefaction project. The annual sublease payment is $0.5 million. The initial term of the sublease expires on December 31, 2034, with options to renew for five 10-year extensions with similar terms as the initial term. The annual sublease payment will be adjusted for inflation every five years based on a consumer price index, as defined in the sublease agreement. We recognized $0.1 million of sublease revenue from SPL as a credit to operating and maintenance expense—affiliate on our Consolidated Statements of Income for each of the three months ended March 31, 2015 and 2014.

LNG Terminal Export Agreement

In January 2010, we and Cheniere Marketing entered into an LNG Terminal Export Agreement that provides Cheniere Marketing the ability to export LNG from our LNG terminal.  We did not record any revenues associated with this agreement during the three months ended March 31, 2015 and 2014.

11

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Cooperation Agreement

We have entered into an agreement with SPL to allow SPL certain rights to access the property and facilities that we own for the purpose of constructing, modifying and operating SPL’s facilities under construction. In consideration for the access we have given, SPL has agreed to transfer title to us of certain facilities, equipment and modifications. The term of this agreement is consistent with our TUA described above. As of both March 31, 2015 and December 31, 2014, SPL had conveyed $0.7 million of assets to us under this agreement.

State Tax Sharing Agreement

In November 2006, we and Cheniere entered into a state tax sharing agreement. 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 computed 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 January 1, 2008.

NOTE 8—RECENT ACCOUNTING STANDARDS

In May 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on revenue recognition. The core principle of this amendment is that an entity should 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 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our consolidated financial position, results of operations and cash flows.

In August 2014, the FASB issued authoritative guidance that 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. This guidance is effective for annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter, with earlier adoption permitted. The adoption of this guidance is not expected to have an impact on our consolidated financial statements or related disclosures.

In February 2015, the FASB amended its guidance on consolidation analysis. This amendment primarily affects asset managers and reporting entities involved with limited partnerships or similar entities, but the analysis is relevant in the evaluation of any reporting organization’s requirement to consolidate a legal entity. This guidance changes (1) the identification of variable interests, (2) the variable interest entity characteristics for a limited partnership or similar entity and (3) the primary beneficiary determination. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our consolidated financial position, results of operations and cash flows.

In April 2015, the FASB issued authoritative guidance that requires 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. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance must be adopted retrospectively to each prior reporting period presented and disclosures will be required for a change in accounting principles. Upon adoption of this standard, the balance of long-term debt, net will be reduced by the balance of debt issuance costs, net on our Consolidated Balance Sheets.

12

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 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, regardless of the source of such information, or the transportation 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 regarding any agreement to be entered into or performed substantially in the future, including any revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification, liquefaction or storage capacities that are, or may become, subject to contracts;

• statements regarding counterparties to our TUAs and other contracts;

• statements regarding our business strategy, our strengths, our business and operation plans or any other plans, forecasts, projections, or objectives, including anticipated revenues and capital expenditures, 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 Securities and Exchange Commission (“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, 2014. 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.

13

Introduction

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

• Overview of Business 

• Liquidity and Capital Resources 

• Results of Operations 

• Off-Balance Sheet Arrangements 

• Summary of Critical Accounting Estimates 

• Recent Accounting Standards

Overview of Business

We own and operate an LNG receiving and regasification terminal in western Cameron Parish, Louisiana, less than four miles from the Gulf Coast on the Sabine Pass deepwater ship channel (our “LNG terminal”). Our LNG terminal includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d.

Liquidity and Capital Resources

Cash and Cash Equivalents

As of March 31, 2015, we had $7.7 million of cash and cash equivalents and $129.1 million of current and non-current restricted cash and cash equivalents, which is restricted to pay interest on the Senior Notes described below.

The foregoing funds and cash flows generated from operations are anticipated to be sufficient to fund our operating expenditures and interest requirements for at least the next twelve months.

TUA Revenues

Our LNG terminal has operational regasification capacity of approximately 4.0 Bcf/d and aggregate LNG storage capacity of approximately 16.9 Bcfe. Approximately 2.0 Bcf/d of the regasification capacity at our LNG terminal has been reserved under two long-term third-party TUAs, under which our customers are required to pay fixed monthly fees, whether or not they use our LNG terminal.  Each of Total Gas & Power North America, Inc. (“Total”) and Chevron U.S.A. Inc. (“Chevron”) has reserved approximately 1.0 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to us aggregating approximately $125 million annually for 20 years that commenced in 2009. Total S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions, and Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.

The remaining approximately 2.0 Bcf/d of capacity has been reserved under a TUA by SPL, a wholly owned subsidiary of Cheniere Partners (NYSE MKT: CQP), a publicly traded partnership which indirectly owns us. SPL is developing liquefaction facilities at our LNG terminal adjacent to our existing regasification facilities in order to liquefy and export natural gas from the United States.  SPL is obligated to make monthly capacity payments to us aggregating approximately $250 million annually, continuing until at least 20 years after SPL delivers its first commercial cargo at SPL’s liquefaction facilities under construction at our LNG terminal. We entered into a terminal use rights assignment and agreement (“TURA”) with SPL and Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which Cheniere Investments has the right to use SPL’s reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to us. Cheniere Partners has guaranteed the obligations of SPL under its TUA and the obligations of Cheniere Investments under the TURA.

Under each of these TUAs, we are entitled to retain 2% of the LNG delivered to our LNG terminal.

14

Capital Resources

As of March 31, 2015, we had an aggregate principal amount of $1.7 billion, before discount, of the 7.50% Senior Secured Notes due 2016 (the “2016 Senior Notes”) and $0.4 billion of the 6.50% Senior Secured Notes due 2020 (the “2020 Senior Notes” and collectively with the 2016 Senior Notes, the “Senior Notes”). Borrowings under the 2016 Senior Notes and 2020 Senior Notes accrue interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Senior Notes and 2020 Senior Notes are substantially similar. Interest on the Senior Notes is payable semi-annually in arrears. Subject to permitted liens, the Senior Notes are secured on a pari passu first-priority basis by a security interest in all of our equity interests and substantially all of our operating assets.

We may redeem all or part of our 2016 Senior Notes at any time at a redemption price equal to 100% of the principal plus any accrued and unpaid interest plus the greater of:

•1.0% of the principal amount of the 2016 Senior Notes; or

• the excess of: (a) the present value at such redemption date of (i) the redemption price of the 2016 Senior Notes plus (ii) all required interest payments due on the 2016 Senior Notes (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the treasury rate as of such redemption date plus 50 basis points; over (b) the principal amount of the 2016 Senior Notes, if greater.

We may redeem all or part of the 2020 Senior Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020 Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. We may also redeem, at our option, all or part of the 2020 Senior Notes at any time prior to November 1, 2016, at a “make-whole” price set forth in the indenture governing the 2020 Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, we may redeem up to 35% of the aggregate principal amount of the 2020 Senior Notes at a redemption price of 106.5% of the principal amount of the 2020 Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the redemption date, in an amount not to exceed the net proceeds of one or more completed equity offerings as long as we redeem the 2020 Senior Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Senior Notes originally issued remains outstanding after the redemption.

Pursuant to the indentures governing the Senior Notes (the “Senior Notes Indentures”), except for permitted tax distributions, we may not make distributions until certain conditions are satisfied, including: (i) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (ii) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Senior Notes Indentures. During the three months ended March 31, 2015 and 2014, we made distributions of $70.8 million and $63.4 million, respectively, after satisfying all the applicable conditions in the Senior Notes Indentures.

15

Sources and Uses of Cash

The following table summarizes (in thousands) the sources and uses of our cash and cash equivalents for the three months ended March 31, 2015 and 2014. 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.

	Three Months Ended March 31,
	2015			2014
Sources of cash and cash equivalents
Operating cash flow	$	19,861		$	62,766
Capital contributions from Cheniere Partners	53,122			—
Property, plant and equipment, net	4			—
Total sources of cash and cash equivalents	72,987			62,766
Uses of cash and cash equivalents
Distributions to limited partner	(70,782		)	(63,437		)
Property, plant and equipment, net	—			(8		)
Total uses of cash and cash equivalents	(70,782		)	(63,445		)
Net increase (decrease) in cash and cash equivalents	2,205			(679		)
Cash and cash equivalents—beginning of period	5,460			14,994
Cash and cash equivalents—end of period	$	7,665		$	14,315

Operating Cash Flow and Capital Contributions from Cheniere Partners

Cash flow from operations was $19.9 million and $62.8 million in the three months ended March 31, 2015 and 2014, respectively. Operating cash flow related primarily to fixed monthly fees paid by our TUA customers. The decreased operating cash flow and the increased capital contributions from Cheniere Partners primarily resulted from the purchase of LNG cargoes used to maintain cryogenic readiness of our LNG terminal. Our TUA customers are obligated to fully reimburse us for their proportional share of the cost of these LNG cargoes.

Distributions to Limited Partner

We made $70.8 million and $63.4 million of distributions to our limited partner in the three months ended March 31, 2015 and 2014, respectively. The increase in distributions to our limited partner in the three months ended March 31, 2015, primarily resulted from the capital contributions from Cheniere Partners, offset by a decrease in operating cash flow.

Results of Operations

There were no significant changes in our revenues or operating costs and expenses in the three months ended March 31, 2015, as compared to the respective period in 2014. We do not expect significant changes in our revenues or operating costs and expenses until SPL begins commercial operations of its liquefaction facilities adjacent to our existing regasification facilities. Additional revenues will primarily consist of LNG loading and tug fees that will be partially offset by additional operating costs and expenses related to these activities.

Off-Balance Sheet Arrangements

As of March 31, 2015, we had no “off-balance sheet arrangements” that may have a current or future material effect on our consolidated financial position or results of operations.

16

Summary of Critical Accounting Estimates

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the consolidated financial statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2014.

Recent Accounting Standards

For descriptions of recently issued accounting standards, see Part 1. Financial Information, Item 1. Notes to Consolidated Financial Statements, Note 8—Recent Accounting Standards.

ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Cash Investments

We have cash investments that we manage based on internal investment guidelines that emphasize liquidity and preservation of capital. Such cash investments are stated at historical cost, which approximates fair market value on our Consolidated Balance Sheets.

Marketing and Trading Commodity Price Risk

We have entered into commodity derivatives to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory (“LNG Inventory Derivatives”). We use one-day value at risk (“VaR”) with a 95% confidence interval and other methodologies for market risk measurement and control purposes of our LNG Inventory Derivatives. The VaR is calculated using the Monte Carlo simulation method. The VaR related to our LNG Inventory Derivatives was $0.5 million as of March 31, 2015.

ITEM 4.CONTROLS AND PROCEDURES

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

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

17

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. In the opinion of management, as of March 31, 2015, there were no pending legal matters that could be reasonably expected to have a material impact on our consolidated results of operations, financial position or cash flows.

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, 2014.

ITEM 5.OTHER INFORMATION

Compliance Disclosure

Pursuant to Section 13(r) of the Exchange Act, if during the quarter ended March 31, 2015, 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 (“ITRA”). During the quarter ended March 31, 2015, we did not engage in any transactions with Iran or with persons or entities related to Iran.

Blackstone CQP Holdco LP, an affiliate of The Blackstone Group L.P. (“Blackstone Group”), is a holder of approximately 29% of the outstanding equity interests of Cheniere Partners and has three representatives on the Board of Directors of Cheniere Partners’ general partner. Accordingly, Blackstone Group may be deemed an “affiliate” of Cheniere Partners, as that term is defined in Exchange Act Rule 12b-2.

We have received notice from Blackstone Group that it may include in its Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2015 disclosures pursuant to ITRA regarding one of its portfolio companies that may be deemed to be an affiliate of Blackstone Group. Because of the broad definition of “affiliate” in Exchange Act Rule 12b-2, this portfolio company of Blackstone Group, through Blackstone Group’s ownership of Cheniere Partners, may also be deemed to be an affiliate of ours. We have received notice from Blackstone Group that Travelport Limited (“Travelport”) has engaged in the following activities: as part of its global business in the travel industry, Travelport provides certain passenger travel-related Travel Commerce Platform and airline IT services to Iran Air and airline IT services to Iran Air Tours. The gross revenues and net profits attributable to such activities during the quarter ended March 31, 2015 have not been reported by Travelport. Blackstone Group has informed us that Travelport intends to continue these business activities with Iran Air and Iran Air Tours as such activities are either exempt from applicable sanctions prohibitions or specifically licensed by the Office of Foreign Assets Control.

18

ITEM 6.EXHIBITS

Exhibit No.	Description
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 of 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.

19

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 LNG, L.P.
		By:	Sabine Pass LNG-GP, LLC,
			its general partner
Date:	April 30, 2015	By:	/s/ Michael J. Wortley
			Michael J. Wortley
			Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)
Date:	April 30, 2015	By:	/s/ Leonard Travis
			Leonard Travis
			Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

20