Sabine Pass LNG 10Q 2010 Q3 Quarterly report

Sabine Pass LNG 10-Q2010 Q3 Quarterly report

Content analysis

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2010

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

For the transition period from to

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 800 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 ¨ 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 definition of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

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.

INDEX TO FORM 10-Q

PART I. FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands)

	September 30, 2010			December 31, 2009
	(unaudited)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	5,178		$	117,411
Restricted cash and cash equivalents		54,929			13,732
Accounts and interest receivable		722			5,037
Accounts receivable—affiliate		—			3,586
Advances to affiliate		2,458			5,358
Advances to affiliate—LNG inventory		—			1,319
LNG inventory		901			1,521
Prepaid expenses and other		5,540			4,594
TOTAL CURRENT ASSETS		69,728			152,558

NON-CURRENT RESTRICTED CASH AND CASH EQUIVALENTS		82,394			82,394
PROPERTY, PLANT AND EQUIPMENT, NET		1,559,573			1,588,557
DEBT ISSUANCE COSTS, NET		23,108			26,953
OTHER		9,973			8,639
TOTAL ASSETS	$	1,744,776		$	1,859,101

LIABILITIES AND PARTNERS’ DEFICIT
CURRENT LIABILITIES
Accounts payable	$	17		$	39
Accounts payable—affiliate		1			287
Accrued liabilities		56,964			22,002
Accrued liabilities—affiliate		2,079			3,095
Deferred revenue		26,340			26,456
Deferred revenue—affiliate		21,592			63,507
TOTAL CURRENT LIABILITIES		106,993			115,386

LONG-TERM DEBT, NET OF DISCOUNT		2,111,921			2,110,101
LONG-TERM DEBT—RELATED PARTY, NET OF DISCOUNT		74,629			72,928
DEFERRED REVENUE		30,500			33,500
DEFERRED REVENUE—AFFILIATE		9,813			7,360
OTHER NON-CURRENT LIABILITIES		319			327
COMMITMENTS AND CONTINGENCIES		—			—
PARTNERS’ DEFICIT		(589,399	)		(480,501	)
TOTAL LIABILITIES AND PARTNERS’ DEFICIT	$	1,744,776		$	1,859,101

See accompanying notes to consolidated financial statements.

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands)

(unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2010			2009			2010			2009

REVENUES
Revenues	$	65,945		$	65,035		$	198,776		$	97,112
Revenues—affiliate		63,426			63,498			191,136			189,665
TOTAL REVENUES		129,371			128,533			389,912			286,777

EXPENSES
Operating and maintenance expense		5,865			4,752			20,107			14,445
Operating and maintenance expense—affiliate		3,017			2,810			9,167			8,393
Depreciation expense		10,538			8,905			31,661			22,711
General and administrative expense		516			415			2,037			858
General and administrative expense—affiliate		2,274			2,294			7,337			7,064
TOTAL EXPENSES		22,210			19,176			70,309			53,471

INCOME FROM OPERATIONS		107,161			109,357			319,603			233,306
OTHER INCOME (EXPENSE)
Interest income		75			62			194			486
Interest expense, net		(43,451	)		(38,089	)		(130,576	)		(104,370	)
Derivative gain, net		—			1,158			460			4,482
Other		—			—			2			12
TOTAL OTHER EXPENSE		(43,376	)		(36,869	)		(129,920	)		(99,390	)
NET INCOME	$	63,785		$	72,488		$	189,683		$	133,916

See accompanying notes to consolidated financial statements.

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			Accumulated Other Comprehensive Income		Total Partners’ Deficit

Balance at December 31, 2009	$	—	$	(480,501	)	$	—	$	(480,501	)
Net income		—		189,683			—		189,683
Distributions		—		(298,581	)		—		(298,581	)
Balance at September 30, 2010	$	—	$	(589,399	)	$	—	$	(589,399	)

See accompanying notes to consolidated financial statements.

SABINE PASS LNG, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Nine Months Ended
	September 30,
	2010			2009
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	189,683		$	133,916
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation		31,661			22,711
Non-cash derivative loss		124			1,639
Amortization of debt issuance costs		3,759			2,863
Amortization of debt discount		3,521			3,521
Investment in restricted cash and cash equivalents		(41,197	)		(41,197	)
Changes in operating assets and liabilities:
Accounts and interest receivable		369			141
Accounts receivable—affiliate		3,586			59
Accounts payable and accrued liabilities		41,070			33,239
Accounts payable and accrued liabilities—affiliate		(1,301	)		1,844
Advances to affiliate		2,900			(4,458	)
Deferred revenue		(3,116	)		21,170
Deferred revenue—affiliate		(41,915	)		—
Prepaid and other		876			227
NET CASH PROVIDED BY OPERATING ACTIVITIES		190,020			175,675

CASH FLOWS FROM INVESTING ACTIVITIES
Use of restricted cash and cash equivalents		—			71,088
LNG receiving terminal construction-in-process, net		(3,636	)		(97,253	)
Advances under long-term contracts		(36	)		(404	)
NET CASH USED IN INVESTING ACTIVITIES		(3,672	)		(26,569	)

CASH FLOWS FROM FINANCING ACTIVITIES
Distributions to owner		(298,581	)		(222,508	)
Debt issuance costs		—			(23	)
NET CASH USED IN FINANCING ACTIVITIES		(298,581	)		(222,531	)

NET DECREASE IN CASH AND CASH EQUIVALENTS		(112,233	)		(73,425	)
CASH AND CASH EQUIVALENTS—beginning of period		117,411			194,827
CASH AND CASH EQUIVALENTS—end of period	$	5,178		$	121,402

See accompanying notes to consolidated financial statements.

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, L.P. have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) for interim financial information and 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. As used in these Notes to Consolidated Financial Statements, the terms “Sabine Pass LNG,” “we”, “us” and “our” refer to Sabine Pass LNG, L.P. and its wholly-owned subsidiaries, unless otherwise stated or indicated by context.

Results of operations for the three- and nine-month periods ended September 30, 2010 are not necessarily indicative of the results of operations that will be realized for the year ended December 31, 2010.

We are not a taxable entity for federal income tax purposes. As such, we do not directly pay federal income tax. Our taxable income or loss, which may vary substantially from the net income or loss reported in the Consolidated Statements of Operations, is includable in the federal income tax returns of each partner. The aggregate difference in the basis of our net assets for financial and income tax purposes cannot be readily determined as we do not have access to the information about each partner’s tax attributes related to us.

Certain reclassifications have been made to prior period information to conform to the current presentation. The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.

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, 2009.

NOTE 2—LNG Inventory and Advances to Affiliate—LNG Inventory

Liquified natural gas (“LNG”) inventory and advances to affiliate—LNG inventory are recorded at cost and are subject to lower of cost or market (“LCM”) adjustments at the end of each period. Inventory cost is determined using the average cost method. Recoveries of losses resulting from interim period LCM adjustments are made due to market price recoveries on the same inventory in the same fiscal year and are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. At September 30, 2010 and December 31, 2009, we had $0.9 million and $1.5 million, respectively, of LNG inventory on our Consolidated Balance Sheets. At September 30, 2010 and December 31, 2009, we had zero and $1.3 million, respectively, of advances to affiliate—LNG inventory on o ur Consolidated Balance Sheets.

NOTE 3—Restricted Cash and Cash Equivalents

Restricted cash and cash equivalents consist of cash and cash equivalents that are contractually restricted as to usage or withdrawal, as follows:

We have issued an aggregate principal amount of $2,215.5 million of Senior Notes (See Note 6—“Long-Term Debt (including related party)”). Under the indenture governing the Senior Notes (the “Sabine Pass Indenture”), except for permitted tax distributions, we may not make distributions until certain conditions are satisfied: 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 there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of $82.4 million. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 an d other conditions specified in the Sabine Pass Indenture.

As of September 30, 2010 and December 31, 2009, we classified $54.9 million and $13.7 million, respectively, as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of September 30, 2010 and December 31, 2009, we classified the permanent debt service reserve fund of $82.4 million as non-current restricted cash and cash equivalents. These cash accounts are controlled by a collateral trustee, and therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets.

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Continued

(unaudited)

NOTE 4—Property, Plant and Equipment

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

	September 30, 2010			December 31, 2009
LNG RECEIVING TERMINAL COSTS
LNG receiving terminal	$	1,628,296		$	1,627,564
LNG receiving terminal construction-in-process		1,837			—
LNG site and related costs, net		171			176
Accumulated depreciation		(71,243	)		(39,975	)
Total LNG receiving terminal costs, net		1,559,061			1,587,765

FIXED ASSETS
Computers and office equipment		227			259
Vehicles		383			421
Machinery and equipment		955			931
Other		482			419
Accumulated depreciation		(1,535	)		(1,238	)
Total fixed assets, net		512			792

PROPERTY, PLANT AND EQUIPMENT, NET	$	1,559,573		$	1,588,557

We began depreciating equipment and facilities associated with our LNG receiving terminal when costs were ready for use. Depreciation expense related to our LNG receiving terminal totaled $10.5 million and $8.8 million for the three-month periods ended September 30, 2010 and 2009, respectively, and totaled $31.3 million and $22.3 million for the nine-month periods ended September 30, 2010 and 2009, respectively.

NOTE 5—Accrued Liabilities

As of September 30, 2010 and December 31, 2009, accrued liabilities consisted of the following (in thousands):

	September 30, 2010		December 31, 2009
Interest expense and related debt fees	$	54,929	$	14,152
LNG receiving terminal construction and operating costs		2,035		7,850
Affiliate		2,079		3,095
Total accrued liabilities	$	59,043	$	25,097

NOTE 6—Long-Term Debt (including related party)

As of September 30, 2010 and December 31, 2009, our long-term debt consisted of the following (in thousands):

	September 30, 2010		December 31, 2009
Senior Notes, net of discount	$	2,111,921	$	2,110,101
Senior Notes, net of discount—related party		74,629		72,928
Total long-term debt, net of discount	$	2,186,550	$	2,183,029

In November 2006, we issued an aggregate principal amount of $2,032.0 million of Senior Notes, consisting of $550.0 million of 7¼% Senior Secured Notes due 2013 (the “2013 Notes”) and $1,482.0 million of 7½% Senior Secured Notes due 2016 (the “2016 Notes” and collectively with the 2013 Notes, the “Senior Notes”). In September 2008, we issued an additional $183.5 million, before discount, of 2016 Notes whose terms were identical to the previously outstanding 2016 Notes. The net proceeds received from the additional issuance of 2016 Notes were $145.0 million. The additional issuance and the previously outstanding 2016 Notes are treated as a single series of notes under the Sabine Pass Indenture.

Interest on the Senior Notes is payable semi-annually in arrears on May 30 and November 30 of each year. 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. Under the Sabine Pass Indenture, except for permitted tax distributions, we may not make distributions until certain conditions are satisfied: 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 there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of $82.4 million. Distributions are permitted only after satisfying the foregoing funding requirement s, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass Indenture. During the three- and nine-month periods ended September 30, 2010, we made distributions of $86.8 million and $298.6 million, respectively, to our owners after satisfying all of the applicable conditions in the Sabine Pass Indenture. During the three- and nine-month periods ended September 30, 2009, we made distributions of $73.2 million and $222.5 million, respectively, to our owners after satisfying all of the applicable conditions in the Sabine Pass Indenture.

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Continued

(unaudited)

NOTE 7—Financial Instruments

Derivative Instruments

Cheniere Marketing, LLC (“Cheniere Marketing”) has entered into financial derivatives on our behalf to hedge the exposure to variability in expected future cash flows attributable to the future sale of LNG inventory. Changes in the fair value of our derivatives are reported in earnings because they do not meet the criteria to be designated as a hedging instrument that is required to qualify for cash flow hedge accounting. The estimated fair value of financial instruments is the amount at which the instrument could be exchanged currently between willing parties. We had no open financial derivative instruments at September 30, 2010.

Other Financial Instruments

The estimated fair value of financial instruments, including those financial instruments for which the fair value option was not elected are set forth in the table below. The carrying amounts reported on our Consolidated Balance Sheets for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, interest receivable and accounts payable approximate fair value due to their short-term nature.

Financial Instruments (in thousands):

	September 30, 2010				December 31, 2009
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2013 Notes (1)	$	550,000	$	530,750	$	550,000	$	503,250
2016 Notes, net of discount (1)		1,636,550		1,493,352		1,633,029		1,371,744

(1)	The fair value of the Senior Notes, net of discount, was based on quotations obtained from broker-dealers who made markets in these and similar instruments as of September 30, 2010 and December 31, 2009, as applicable.

NOTE 8—Related Party Transactions

As of September 30, 2010 and December 31, 2009, we had $2.5 million and $5.4 million of advances to affiliates, respectively. In addition, we have entered into the following related party transactions:

Terminal Use Agreement

In November 2006, Cheniere Marketing reserved approximately 2.0 billion cubic feet per day (“Bcf/d”) of regasification capacity under a firm commitment terminal use agreement (“TUA”) with us and was required to make capacity reservation fee payments aggregating approximately $250 million per year for the period from January 1, 2009, through at least September 30, 2028. Cheniere Energy, Inc. (“Cheniere”) guaranteed Cheniere Marketing’s obligations under its TUA.

In June 2010, Cheniere Marketing assigned its existing TUA with us to Cheniere Energy Investments, LLC (“Investments”), a wholly-owned subsidiary of Cheniere Energy Partners, L.P. (“Cheniere Partners”), including all of its

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Continued

(unaudited)

rights, titles, interests, obligations and liabilities in and under the TUA. In connection with the assignment, Cheniere’s guarantee of Cheniere Marketing’s obligations under the TUA was terminated. Investments is required to make capacity payments under the TUA aggregating approximately $250 million per year through at least September 30, 2028. Cheniere Partners has guaranteed Investments’ obligations under its TUA.

LNG Lease Agreement

In September 2008, we entered into an agreement in the form of a lease with Cheniere Marketing that enabled us to hedge the exposure to variability in expected future cash flows of its commissioning cargoes. The agreement permitted Cheniere Marketing to deliver LNG to our LNG receiving terminal and to receive regasified LNG for redelivery as natural gas in exchange for the use of the properties of the LNG to cool down our LNG receiving terminal. Under the terms of the agreement, we paid Cheniere Marketing a fixed fee based on the delivered quantity of LNG in each LNG cargo. We assumed full price risk of the purchase and sale of the LNG and also financed all activities relating to the LNG. Cheniere Marketing held title to the LNG at all times and sold all redelivered LNG and remitted the net proceeds from such sales back to us.

Advances to affiliate—LNG inventory is recorded at cost and is subject to LCM adjustments at the end of each period. Inventory cost is determined using the average cost method. Recoveries of losses resulting from interim period LCM adjustments are made due to market price recoveries on the same inventory in the same fiscal year and are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. At September 30, 2010 and December 31, 2009, we had zero and $1.3 million, respectively, advances to affiliate—LNG inventory on our Consolidated Balance Sheets. During the three- and nine-month periods ended September 30, 2010 and 2009, we incurred fixed fees from Cheniere Marketing of zero and $0.3 million, respectively.

Service Agreements

In February 2005, we entered into a 20-year operation and maintenance agreement with a wholly-owned subsidiary of Cheniere pursuant to which we receive all necessary services required to construct, operate and maintain our LNG receiving terminal. We are required to pay a fixed monthly fee of $130,000 (indexed for inflation) under the agreement, 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.

In February 2005, we entered into a 20-year management services agreement with our general partner, which is a wholly-owned subsidiary of Cheniere Partners, pursuant to which our general partner was appointed to manage the construction and operation of our LNG receiving terminal, excluding those matters provided for under the operation and maintenance agreement described in the paragraph above. In August 2008, our general partner assigned all of its rights and obligations under the management services agreement to Cheniere LNG Terminals, Inc. (“Cheniere Terminals”), a wholly-owned subsidiary of Cheniere. We are required to pay Cheniere Terminals a monthly fixed fee of $520,000 (indexed for inflation).

During the three-month periods ended September 30, 2010 and 2009, we paid an aggregate of $1.9 million and $2.0 million, respectively, under the foregoing service agreements. During the nine-month periods ended September 30, 2010 and 2009, we paid an aggregate of $5.9 million and $6.1 million, respectively.

Agreement to Fund Our Cooperative Endeavor Agreements

In July 2007, we executed Cooperative Endeavor Agreements (“CEAs”) with various Cameron Parish, Louisiana taxing authorities that allow them to collect certain annual property tax payments from us in 2007 through 2016. This ten-year initiative represents an aggregate $25.0 million commitment and 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 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 receiving terminal starting in 2019. In September 2007, we modified our TUA with Cheniere Marketing, pursuant to which Cheniere Marketing will 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 existing TUA to Investments and concurrently entered into a Variable Capacity Rights Agreement (“VCRA”), allowing Cheniere Marketing to continue to monetize

SABINE PASS LNG, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Continued

(unaudited)

Investments’ capacity under the TUA after the assignment. The VCRA provides that Cheniere Marketing will continue to fund the CEAs during the term of the VCRA and in exchange Cheniere Marketing will receive any future credits.

On a consolidated basis, these TUA payments were recorded to other assets, and payments from Cheniere Marketing that we utilized to make the ad valorem tax payments were recorded as deferred revenue. As of September 30, 2010 and December 31, 2009, we had $9.8 million and $7.4 million of other assets and deferred revenue resulting from our ad valorem tax payments and the advance TUA payments received from Cheniere Marketing, respectively.

Contracts for Sale and Purchase of Natural Gas

During the three- and nine-month periods ended September 30, 2010, we sold or purchased natural gas for fuel under an agreement with Cheniere Marketing. Under this agreement, we purchase natural gas from Cheniere Marketing to use as fuel at our LNG receiving terminal at a sales price equal to the actual purchase cost paid by Cheniere Marketing to suppliers of the natural gas plus any third-party costs incurred by Cheniere Marketing in respect of the receipt, purchase, and delivery of the natural gas to our LNG receiving terminal and plus an administrative fee paid to Cheniere Marketing. We purchased $1.2 million and $1.8 million of natural gas from Cheniere Marketing under this contract for the three- and nine-month periods ended September 30, 2010, respectively. We did not purchase any natural gas from Cheniere Marketing under this contract for the three- and nine-month periods ended September 30, 2009.

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 receiving terminal. We received zero and $0.9 million under this contract for the three- and nine-month periods ended September 30, 2010, respectively.

NOTE 9—Supplemental Cash Flow Information and Disclosures of Non-Cash Transactions

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

	Nine Months Ended September 30,
	2010		2009
Cash paid for interest, net of amounts capitalized	$	82,340	$	56,767
Construction in process and debt issuance additions funded with accrued liabilities		—		7,916

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact, 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 natural gas production, supply or consumption; future levels of liquefied natural gas (“LNG”) imports into North America; sales of natural gas in North America; and the transportation, other infrastructure or prices related to natural gas, LNG or other energy sources;

•

statements regarding any financing transactions or arrangements, or ability to enter into such transactions or arrangements;

•

statements regarding any terminal use agreement (“TUA”) or other agreements to be entered into or performed substantially in the future, including any cash distributions and revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification or storage capacity that are, or may become, subject to TUAs or other contracts;

•

statements regarding counterparties to our TUAs, construction contracts and other contracts;

•

statements regarding any business strategy, any business plans or any other plans, forecasts, projections or objectives, any or all of which are subject to change;

•

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

•

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

These forward-looking statements are often identified by the use of terms such as “achieve,” “anticipate,” “believe,” “estimate,” “expect,” “forecast,” “intend,” “plan,” “potential,” “project,” “propose,” “strategy” and similar terms. Although we believe that the expectations reflected in these forward-looking statements are reasonable, they involve assumptions, risks and uncertainties, and these expectations may prove to be incorrect. You should not place undue reliance on these forward-looking statements, which speak only as of the date of this quarterly report.

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 current report on Form 8-K dated August 6, 2010. 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 consolidated financial statements and the accompanying notes in Item 1. “Consolidated Financial Statements.” 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

•

Liquidity and Capital Resources

•

Results of Operations

•

Off-Balance Sheet Arrangements

•

Summary of Critical Accounting Policies and Estimates

•

Recent Accounting Standards

Overview of Business

In 2003, we were formed by Cheniere Energy, Inc. (“Cheniere”) to own, develop and operate the Sabine Pass LNG receiving terminal. We are a Houston-based partnership formed with one general partner, Sabine Pass LNG-GP, LLC (“Sabine Pass GP”), formerly Sabine Pass LNG-GP, Inc., an indirect subsidiary of Cheniere, and one limited partner, Sabine Pass LNG-LP, LLC (“Sabine Pass LNG-LP”), an indirect subsidiary of Cheniere. Cheniere has a 90.6% ownership interest in Cheniere Energy Partners, L.P. (“Cheniere Partners”), which is the 100% parent of Sabine Pass GP and Sabine Pass LNG-LP and, indirectly, us.

Following the achievement of commercial operability of our LNG receiving terminal in September 2008, we began receiving capacity reservation fee payments from Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly-owned subsidiary of Cheniere, under its TUA. In December 2008, Cheniere Marketing began paying us its monthly capacity reservation fee payment on a quarterly basis. We also began receiving monthly capacity reservation fee payments from Total Gas and Power North America, Inc. (formerly known as Total LNG USA, Inc.) (“Total”) and Chevron U.S.A., Inc. (“Chevron”) under their TUAs in March 2009 and June 2009, respectively.

In June 2010, Cheniere Marketing assigned its TUA with us to Cheniere Energy Investments, LLC (“Investments”), a wholly owned subsidiary of Cheniere Partners, including all of its rights, titles, interests, obligations and liabilities in and under the TUA, as amended, between Cheniere Marketing and us. In connection with the assignment, Cheniere’s guarantee of Cheniere Marketing’s obligations under the TUA was terminated. Investments is required to make capacity payments aggregating approximately $250 million per year through at least September 30, 2028. Cheniere Partners has guaranteed Investments’ obligations under its TUA.

Our Business

Our LNG receiving terminal has regasification capacity of approximately 4.0 billion cubic feet per day (“Bcf/d”) and five LNG storage tanks with an aggregate LNG storage capacity of approximately 16.9 Bcf along with two unloading docks capable of handling the largest LNG carriers currently being operated or built. Construction of our LNG receiving terminal commenced in March 2005. We achieved full operability with total sendout capacity of approximately 4.0 Bcf/d and storage capacity of approximately 16.9 Bcf during the third quarter of 2009.

Liquidity and Capital Resources

Cash and Cash Equivalents

As of September 30, 2010, we had $5.2 million of cash and cash equivalents and $137.3 million of restricted cash and cash equivalents, which is restricted to pay interest on the Senior Notes described below.

The foregoing funds are anticipated to be sufficient to fund operating expenditures and interest requirements. Regardless whether we receive revenues from Investments (or Cheniere Partners, as guarantor), we expect to have sufficient cash flow from payments made under our Total and Chevron TUAs to allow us to meet our future operating expenditures and interest payment requirements until maturity of the 2013 Notes. However, we must satisfy certain restrictions under the indenture governing the Senior Notes (“Sabine Pass Indenture”) before being able to make distributions to our limited partner, which will require that Investments make a substantial portion of its TUA payments to us. Investments has a limited operating history, limited capital and no credit rating. If we are unable to make cash distributions to our limited partner, then Investments will likely be unable to meet its ongoing TUA payments and Cheniere Partners would not be able to satisfy its guarantee obligations to us.

TUA Revenues

The entire approximately 4.0 Bcf/d of regasification capacity at our LNG receiving terminal has been fully reserved under three 20-year, firm commitment TUAs. 2.0 Bcf/d is contracted with unaffiliated third parties, and 2.0 Bcf/d is contracted with Investments. Each of the three customers at our LNG receiving terminal must make the full contracted amount of capacity reservation fee payments under its TUA whether or not it uses any of its reserved capacity. Capacity reservation fee TUA payments are made by our third-party customers as follows:

•

Total has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to us aggregating approximately $125 million per year for 20 years that commenced on April 1, 2009. Total, S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions; and

•

Chevron has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to us aggregating approximately $125 million per year for 20 years that commenced on July 1, 2009. Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.

In June 2010, we entered into amendments of the TUAs with Total and Chevron for the purpose of clarifying various operational rights and obligations of the parties. In connection with these amendments, Total and Chevron have agreed to minimum pro rata inventory obligations as necessary to ensure cryogenic readiness of our LNG receiving terminal and to mitigate the effects of inventory weathering. In addition, Total and Chevron have each agreed to daily boil-off gas re-delivery obligations, service fees related to the compression services associated with minimization of their respective daily boil-off gas re-delivery obligations and pro-rata obligations for the incremental fuel associated with these compression services. Additional items clarified in these amendments include the recognition of inventory transfers between parties and procedural obligations related to daily and monthly informational postings, gas re-delivery and vessel nominations and delivery point flexibility.

Each of Total and Chevron previously paid us $20.0 million in nonrefundable advance capacity reservation fees, which are being amortized over a 10-year period as a reduction of each customer’s regasification capacity reservation fees payable under its respective TUA.

In addition, pursuant to the assignment agreement with Cheniere Marketing as discussed above, Investments has reserved the remaining 2.0 Bcf/d of regasification capacity and 6.9 Bcfe of storage capacity at our LNG receiving terminal. Investments is required to make capacity payments aggregating approximately $250 million per year through at least September 30, 2028. Cheniere Partners has guaranteed Investments’ obligations under its TUA.

Under each of these TUAs, we are entitled to retain 2% of the LNG delivered for the customer’s account, which we will use primarily as fuel for revaporization and self-generated power at our LNG receiving terminal.

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash and cash equivalents for the nine-month periods ended September 30, 2010 and 2009 (in thousands). The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, that are referred to elsewhere in this report. Additional discussion of these items follows the table.

	Nine Months Ended September 30,
	2010			2009
SOURCES OF CASH AND CASH EQUIVALENTS
Operating cash flow	$	190,020		$	175,675
Use of restricted cash and cash equivalents		—			71,088
Total sources of cash and cash equivalents		190,020			246,763

USES OF CASH AND CASH EQUIVALENTS
Distribution to owners		(298,581	)		(222,508	)
LNG receiving terminal construction-in-process, net		(3,636	)		(97,253	)
Other		(36	)		(427	)
Total uses of cash and cash equivalents		(302,253	)		(320,188	)

NET DECREASE IN CASH AND CASH EQUIVALENTS		(112,233	)		(73,425	)
CASH AND CASH EQUIVALENTS—beginning of period		117,411			194,827
CASH AND CASH EQUIVALENTS—end of period	$	5,178		$	121,402

Operating cash flow

Operating cash flow increased $14.3 million for the nine-month period ended September 30, 2010 compared to the same period in 2009. The increase in operating cash flow was a result of obtaining full TUA reservation fee payments from Total and Chevron in the first nine months of 2010 compared to receiving seven payments from Total and four payments from Chevron in the first nine months of 2009, which resulted in $74.3 million of increased operating cash flow. This increase was offset by a decrease in TUA payments that we received from affiliates. In 2009, Cheniere Marketing began making its TUA payments, on a voluntary basis, quarterly; however, in June 2010, after the assignment of the TUA from Cheniere Marketing to Investments, Investments began making its TUA payments on a monthly basis. This change in the timing of affiliate TUA payments resulted in a $41.0 million decrease in operating cash flow for the nine-month period ended September 30, 2010 compared to the same period in 2009. The remaining changes in operating cash flow resulted primarily from timing in operating and maintenance payments.

Use of restricted cash and cash equivalents

During the nine-month period ended September 30, 2009, $71.1 million of restricted cash and cash equivalents was used to pay construction activities at our LNG receiving terminal. The decreased use of restricted cash and cash equivalents during the nine-month period ended September 30, 2010 primarily resulted from substantially completing construction of our LNG receiving terminal during the third quarter of 2009.

Distributions to owners

During the nine-month periods ended September 30, 2010 and 2009, we made $298.6 million and $222.5 million, respectively, in distributions to our owners after satisfying conditions in the Sabine Pass Indenture discussed below.

LNG receiving terminal construction-in-process, net

LNG receiving terminal construction-in-process, net (“CIP”) decreased $93.6 million for the nine-month period ended September 30, 2010 compared to the same period in 2009. The decrease in CIP resulted from substantial completion of our LNG receiving terminal’s construction activities during the third quarter of 2009.

Debt Agreements

Senior Notes

We have issued an aggregate principal amount of $2,215.5 million of Senior Notes consisting of $550.0 million of 7¼% Senior Secured Notes due 2013 and $1,665.5 million of 7½% Senior Secured Notes due 2016. Interest on the Senior Notes is payable semi-annually in arrears on May 30 and November 30 of each year. 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. Under the Sabine Pass Indenture governing the Senior Notes, except for permitted tax distributions, we may not make distributions until certain conditions are satisfied: 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-annua l interest payment, and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of $82.4 million. 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 Sabine Pass Indenture. During the three- and nine-month periods ended September 30, 2010, we made distributions of $86.8 million and $298.6 million, respectively, to our owners after satisfying all of the applicable conditions in the Sabine Pass Indenture. During the three- and nine-month periods ended September 30, 2009, we made distributions of $73.2 million and $222.5 million, respectively, to our owners after satisfying all of the applicable conditions in the Sabine Pass Indenture.

Services Agreements

During the three-month periods ended September 30, 2010 and 2009, we paid an aggregate of $1.9 million and $2.0 million, respectively, under the foregoing service agreements from restricted cash and cash equivalents. During the nine-month periods ended September 30, 2010 and 2009, we paid an aggregate of $5.9 million and $6.1 million, respectively, under the foregoing service agreements from restricted cash and cash equivalents.

State Tax Sharing Agreement

In November 2006, we entered into a state tax sharing agreement with Cheniere effective for tax returns first due on or after January 1, 2008. Under this agreement, Cheniere has agreed to prepare and file all Texas franchise tax returns which it and we are required to file on a combined basis and to timely pay the combined tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the Texas franchise tax that we would be required to pay if our Texas franchise tax liability were computed on a separate company basis. This agreement contains similar provisions for other state and local taxes that we and Cheniere are required to file on a combined, consolidated or unitary basis.

Results of Operations

Three-Month Period Ended September 30, 2010 vs. Three-Month Period Ended September 30, 2009

Overall Operations

Our consolidated net income decreased $8.7 million, from $72.5 million in the three-month period ended September 30, 2009 to $63.8 million in the three-month period ended September 30, 2010. This decrease in net income primarily resulted from increased interest expense, increased operating and maintenance expense (including affiliate expense), increased depreciation expense and decreased derivative gain that was partially offset by increased revenues.

Interest Expense, net

Interest expense, net of amounts capitalized, increased $5.4 million, from $38.1 million in the three-month period ended September 30, 2009 to $43.5 million in the three-month period ended September 30, 2010. This increase resulted from the achievement of full operability of our LNG receiving terminal in the third quarter of 2009, which reduced the amount of interest expense that was capitalized.

Operating and Maintenance Expense (including Affiliate Expense)

Operating and maintenance expense (including affiliate expense) increased $1.3 million, from $7.6 million in the three-month period ended September 30, 2009 to $8.9 million in the three-month period ended September 30, 2010. This increase primarily resulted from increased fuel costs resulting from achieving full operability of our LNG receiving terminal with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity in the third quarter of 2009.

Depreciation Expense

Depreciation expense increased $1.6 million, from $8.9 million in the three-month period ended September 30, 2009 to $10.5 million in the three-month period ended September 30, 2010. This increase resulted from our beginning to depreciate the costs associated with the achievement of full operability of our LNG receiving terminal in the third quarter of 2009.

Derivative Gain

Derivative gain decreased $1.2 million, from $1.2 million in the three-month period ended September 30, 2009 to zero in the three-month period ended September 30, 2010. During three-month period ended September 30, 2009, Cheniere Marketing had entered into financial derivatives on our behalf to hedge the exposure to variability in expected future cash flows attributable to the future sale of LNG inventory. We had no open financial derivative instruments during the three-month period ended September 30, 2010.

Revenues

Revenues increased $0.9 million, from $128.5 million in the three-month period ended September 30, 2009 to $129.4 million in the three-month period ended September 30, 2010. This increase primarily resulted from increased customer LNG delivered to our LNG receiving terminal in the three month period ended September 30, 2010 as compared to the same period in 2009 that resulted in increased retainage revenues. Retainage revenues represent the 2% of LNG delivered for our customer’s account that we are entitled to under each of our TUAs.

Nine-Month Period Ended September 30, 2010 vs. Nine-Month Period Ended September 30, 2009

Overall Operations

Our consolidated net income increased $55.8 million, from $133.9 million in the nine-month period ended September 30, 2009 to $189.7 million in the nine-month period ended September 30, 2010. This increase in net income primarily resulted from increased third-party TUA revenues that were partially offset by increased interest expense, increased depreciation expense, and increased operating and maintenance expense (including affiliate expense).

Revenues

Revenues increased $103.1 million, from $286.8 million in the nine-month period ended September 30, 2009 to $389.9 million in the nine-month period ended September 30, 2010. This increase primarily resulted from the commencement of services under our Total TUA beginning on April 1, 2009 and our Chevron TUA beginning on July 1, 2009.

Interest Expense, net

Interest expense, net of amounts capitalized, increased $26.2 million, from $104.4 million in the nine-month period ended September 30, 2009 to $130.6 million in the nine-month period ended September 30, 2010. This increase resulted from the achievement of full operability of our LNG receiving terminal in the third quarter of 2009, which reduced the amount of interest expense that was capitalized.

Depreciation Expense

Depreciation expense increased $9.0 million, from $22.7 million in the nine-month period ended September 30, 2009 to $31.7 million in the nine-month period ended September 30, 2010. This increase resulted from beginning to depreciate the costs associated with the achievement of full operability of our LNG receiving terminal in the third quarter of 2009.

Operating and Maintenance Expense (including Affiliate Expense)

Operating and maintenance expense (including affiliate expense) increased $6.5 million, from $22.8 million in the nine-month period ended September 30, 2009 to $29.3 million in the nine-month period ended September 30, 2010. This increase primarily resulted from increased tug service costs and increased fuel costs associated with the full operability of our LNG receiving terminal during the entire nine-month period ended September 30, 2010, as compared to only a portion of the nine-month period ended September 30, 2009.

Off-Balance Sheet Arrangements

As of September 30, 2010, we had no “off-balance sheet arrangements” that may have a current or future material affect on our consolidated financial position or results of operations.

Summary of Critical Accounting Policies and Estimates

The selection and application of accounting policies is an important process that has developed as our business activities have evolved and as the accounting rules have developed. Accounting rules generally do not involve a selection among alternatives but involve an implementation and interpretation of existing rules, and the use of judgment, to apply the accounting rules to the specific set of circumstances existing in our business. In preparing our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”), we endeavor to comply properly with all applicable rules on or before their adoption, and we believe that the proper implementation and consistent application of the accounting rules are critical. However, not all situations are specifically addressed in the accounting literature. In these cases, we must use our best judgment to adopt a policy for accounting for these situations. We accomplish this by analogizing to similar situations and the accounting guidance governing them.

Accounting for LNG Activities

Generally, expenditures for direct construction activities, major renewals and betterments are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred.

We capitalized interest and other related debt costs during the construction period of our LNG receiving terminal. Upon commencement of operations, capitalized interest, as a component of the total cost, has been amortized over the estimated useful life of the asset.

Revenue Recognition

LNG regasification capacity reservation fees are recognized as revenue over the term of the respective TUAs. Advance capacity reservation fees are initially deferred and amortized over a 10-year period as a reduction of a customer’s regasification capacity reservation fees payable under its TUA. The retained 2% of LNG delivered for each customer’s

account at our LNG receiving terminal is recognized as revenues as we perform the services set forth in each customer’s TUA.

Use of 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. Actual results could differ from our estimates and assumptions used.

Items subject to estimates and assumptions include, but are not limited to, the carrying amount of property, plant and equipment. Actual results could differ significantly from our estimates.

Recent Accounting Standards

In January 2010, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance which requires additional disclosures and clarifies certain existing disclosure requirements regarding fair value measurements. This guidance is effective for interim and annual reporting periods beginning after December 15, 2009. We adopted this guidance effective January 1, 2010. However, none of the specific additional disclosure requirements were applicable to us at the time of filing this report. (See Note 7—“Financial Instruments” of our Notes to Consolidated Financial Statements for our fair value measurement disclosures.)

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

Cheniere Marketing has entered into exchange-cleared NYMEX natural gas swaps on our behalf to hedge the exposure to variability in expected future cash flows related to the future sale of LNG inventory. We use value at risk (“VaR”) and other methodologies for market risk measurement and control purposes. The VaR is calculated using the Monte Carlo simulation method. At September 30, 2010 and December 31, 2009, the one-day VaR with a 95% confidence interval on our derivative positions was zero and less than $0.1 million, respectively.

As of September 30, 2010, Cheniere Marketing had entered into no financial derivative instruments on our behalf.

Item 4.

Disclosure Controls and Procedures

We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our 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.

PART II. OTHER INFORMATION

Item 1.

Legal Proceedings

In the future, we or any of our subsidiaries may 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 of our general partner, as of September 30, 2010, there were no known threatened or pending legal matters that could reasonably be expected to have a material adverse impact on our consolidated results of operations, financial position or cash flows.

Item 6.	Exhibits

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

*	Filed herewith.
**	Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities and 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

/s/ JERRY D. SMITH

Jerry D. Smith

Chief Accounting Officer of Sabine Pass LNG-GP, LLC, general partner of Sabine Pass LNG, L.P.

(on behalf of the registrant and as principal accounting officer)

Date: November 4, 2010

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