- Report of Foreign Issuer (6-K)

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 6-K

Report of Foreign Private Issuer

Pursuant to Rule 13a-16 or 15d-16 of
the Securities Exchange Act of 1934

For the quarterly period ended March 31, 2009

Commission file number 1- 33198

TEEKAY OFFSHORE PARTNERS L.P.

(Exact name of Registrant as specified in its charter)

4 ^th Floor, Belvedere Building, 69 Pitts Bay Road, Hamilton, HM 08, Bermuda
(Address of principal executive office)

Indicate by check mark whether the registrant files or will file annual reports under cover Form 20-F or Form 40-F.

Form 20-F þ Form 40- F o

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1).

Yes o No þ

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7).

Yes o No þ

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934.

Yes o No þ

If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): 82-

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES

REPORT ON FORM 6-K FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2009

INDEX


	PAGE
PART I: FINANCIAL INFORMATION

Item 1. Financial Statements (Unaudited)

Unaudited Consolidated Statements of Income (Loss) for the three months ended March 31, 2009 and 2008		3

Unaudited Consolidated Balance Sheets as at March 31, 2009 and December 31, 2008		4

Unaudited Consolidated Statements of Cash Flows for the three months ended March 31, 2009 and 2008		5

Unaudited Consolidated Statements of Changes In Total Equity for the three months ended March 31, 2009		6

Notes to the Unaudited Consolidated Financial Statements		7

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		17

Item 3. Quantitative and Qualitative Disclosures about Market Risk		25

PART II: OTHER INFORMATION		26

SIGNATURES		27

Page 2 of 27

ITEM 1 — FINANCIAL STATEMENTS

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES (Note 1)

UNAUDITED CONSOLIDATED STATEMENTS OF INCOME (LOSS)

(in thousands of U.S. dollars, except unit and per unit data)


	Three Months Ended March 31,
	2009			2008
	$			$
VOYAGE REVENUES (including $33,646 and $40,019 for 2009 and 2008, respectively, from related parties — notes 7a, 7b and 7c)		183,425			204,932


OPERATING EXPENSES
Voyage expenses		24,813			51,377
Vessel operating expenses (including ($396) for 2008 from related parties — note 7i, note 8 )		50,734			41,931
Time-charter hire expense (including $1,800 for 2009 from related parties — note 7k )		32,145			33,646
Depreciation and amortization		34,531			32,912
General and administrative (including $9,855 and $12,817 for 2009 and 2008, respectively, from related parties — notes 7d, 7e, 7f and 7g, note 8)		11,922			15,826
Restructuring charge (note 6)		2,201			—

Total operating expenses		156,346			175,692


Income from vessel operations		27,079			29,240


OTHER ITEMS
Interest expense ( notes 5 and 8)		(10,568	)		(21,266	)
Interest income		826			1,249
Realized and unrealized gains (losses) on non-designated derivatives ( note 8 )		17,584			(45,415	)
Foreign currency exchange loss (note 8)		(2,248	)		(2,463	)
Other income — net (note 6)		3,081			3,342

Total other items		8,675			(64,553	)

Income (loss) before income tax expense		35,754			(35,313	)
Income tax expense (note 9)		(4,138	)		(913	)

Net income (loss)		31,616			(36,226	)

Non-controlling interest in net income (loss)		14,676			(23,477	)
Dropdown Predecessor’s interest in net income (note 1)		—			485
General partner’s interest in net income (loss)		616			(265	)
Limited partners’ interest: (note 12)
Net income (loss)		16,324			(12,969	)
Net income (loss) per:
- Common unit (basic and diluted)		0.54			(0.66	)
- Subordinated unit (basic and diluted)		0.54			(0.66	)
- Total unit (basic and diluted)		0.54			(0.66	)


Weighted average number of units outstanding:
- Common units (basic and diluted)		20,425,000			9,800,000
- Subordinated units (basic and diluted)		9,800,000			9,800,000
- Total units (basic and diluted)		30,225,000			19,600,000

Cash distributions declared per unit		0.45			0.40

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

Page 3 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES (Note 1)

UNAUDITED CONSOLIDATED BALANCE SHEETS

(in thousands of U.S. dollars)


	As at			As at
	March 31,			December 31,
	2009			2008
	$			$
ASSETS
Current
Cash and cash equivalents (note 5)		147,837			131,488
Accounts receivable, net		34,177			39,500
Net investment in direct financing leases — current		23,052			22,941
Prepaid expenses		21,966			25,334
Due from affiliate (note 7l)		11,221			10,110
Other current assets		2,259			2,585


Total current assets		240,512			231,958


Vessels and equipment (note 5)
At cost, less accumulated depreciation of $826,173 (December 31, 2008 - $793,918)		1,680,279			1,708,006
Net investment in direct financing leases		50,070			55,710
Other assets		11,190			12,015
Intangible assets — net — shuttle tanker segment (note 4)		43,026			45,290
Goodwill — shuttle tanker segment		127,113			127,113


Total assets		2,152,190			2,180,092


LIABILITIES AND TOTAL EQUITY
Current
Accounts payable		7,596			9,901
Accrued liabilities		50,348			44,467
Due to affiliate (note 7l)		11,714			8,715
Current portion of long-term debt (note 5)		118,598			125,503
Current portion of derivative instruments (note 8)		48,815			54,937
Due to joint venture partners		22,207			21,019


Total current liabilities		259,278			264,542


Long-term debt (note 5)		1,435,656			1,440,933
Deferred income tax		17,479			12,648
Derivative instruments (note 8)		105,750			138,374
Other long-term liabilities		20,572			21,346


Total liabilities		1,838,735			1,877,843

Commitments and contingencies (notes 5, 8 and 10)

Total equity
Partners’ equity		120,403			117,910
Non-controlling interest		206,102			201,383
Accumulated other comprehensive loss		(13,050	)		(17,044	)


Total equity		313,455			302,249


Total liabilities and equity		2,152,190			2,180,092

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

Page 4 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES (Note 1)

UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands of U.S. dollars)


	Three Months Ended March 31,
	2009			2008
	$			$
Cash and cash equivalents provided by (used for)

OPERATING ACTIVITIES
Net income (loss)		31,616			(36,226	)

Non-cash items:
Unrealized (gain) loss on derivative instruments (note 8)		(30,914	)		45,207
Depreciation and amortization		34,531			32,912
Income tax expense		4,138			913
Foreign currency exchange loss and other — net		2,252			4,413
Change in non-cash working capital items related to operating activities		16,830			7,093
Expenditures for drydocking		(4,571	)		(6,301	)

Net operating cash flow		53,882			48,011


FINANCING ACTIVITIES
Proceeds from issuance of long-term debt		—			111,338
Scheduled repayments of long-term debt		(7,182	)		(8,044	)
Prepayments of long-term debt		(5,000	)		(17,000	)
Cash distributions paid		(28,326	)		(32,019	)
Net advances to affiliates		—			(45,331	)
Net advance from joint venture partners		221			—
Other		(289	)		(287	)

Net financing cash flow		(40,576	)		8,657


INVESTING ACTIVITIES
Expenditures for vessels and equipment		(2,486	)		(46,026	)
Investment in direct financing lease assets		—			(17	)
Direct financing lease payments received		5,529			5,942

Net investing cash flow		3,043			(40,101	)


Increase in cash and cash equivalents		16,349			16,567
Cash and cash equivalents, beginning of the period		131,488			121,224

Cash and cash equivalents, end of the period		147,837			137,791

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

Page 5 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES (Note 1)

UNAUDITED CONSOLIDATED STATEMENTS OF CHANGES IN TOTAL EQUITY

(in thousands of U.S. dollars and units)


														Accumulated
	PARTNERS’ EQUITY													Other			Non-
	Limited Partners										General			Comprehensive			controlling
	Common					Subordinated					Partner			Loss			Interest			Total
	Units		$			Units		$			$			$			$			$
Balance as at December 31, 2008 ( note 12 )		20,425		246,646			9,800		(135,900	)		7,164			(17,044	)		201,383			302,249
Net income ( note 12 )				11,031					5,293			616						14,676			31,616
Unrealized net gain on qualifying cash flow hedging instruments (note 8)															1,204			1,156			2,360
Realized net loss on qualifying cash flow hedging instruments (note 8)															2,790			2,766			5,556


Comprehensive income																					39,532


Cash distributions				(9,191	)				(4,410	)		(846	)					(13,879	)		(28,326	)

Balance as at March 31, 2009		20,425		248,486			9,800		(135,017	)		6,934			(13,050	)		206,102			313,455

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

Page 6 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES

NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

(all tabular amounts stated in thousands of U.S. dollars, except unit and per unit data)

1.		Summary of Significant Accounting Policies

		Basis of presentation

		The unaudited interim consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (or GAAP ). These financial statements include the accounts of Teekay Offshore Partners L.P., which is a limited partnership organized under the laws of the Republic of The Marshall Islands, its wholly owned or controlled subsidiaries and the Dropdown Predecessor, as described below (collectively, the Partnership ). The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates.

		Certain information and footnote disclosures required by GAAP for complete annual financial statements have been omitted and, therefore, these interim financial statements should be read in conjunction with the Partnership’s audited consolidated financial statements for the year ended December 31, 2008, which are included on Form 20-F filed on June 29, 2009. In the opinion of management of our general partner, Teekay Offshore GP L.L.C. (or the General Partner ), these interim unaudited consolidated financial statements reflect all adjustments, of a normal recurring nature, necessary to present fairly, in all material respects, the Partnership’s consolidated financial position, results of operations, changes in total equity and cash flows for the interim periods presented. The results of operations for the interim periods presented are not necessarily indicative of those for a full fiscal year. Significant intercompany balances and transactions have been eliminated upon consolidation.

		As required by Statement of Financial Accounting Standards (or SFAS ) No. 141, Business Combinations (or SFAS No. 141 ), the Partnership accounted for the acquisition of interests in vessels from Teekay Corporation as a transfer of a business between entities under common control. The method of accounting prescribed by SFAS No. 141 for such transfers is similar to pooling of interests method of accounting. Under this method, the carrying amount of net assets recognized in the balance sheets of each combining entity is carried forward to the balance sheet of the combined entity, and no other assets or liabilities are recognized as a result of the combination. The excess of the proceeds paid, if any, by the Partnership over Teekay Corporation’s historical cost is accounted for as an equity distribution to Teekay Corporation. In addition, transfers of net assets between entities under common control are accounted for as if the transfer occurred from the date that the Partnership and the acquired vessels were both under common control of Teekay Corporation and had begun operations. As a result, the Partnership’s financial statements prior to the date the interests in these vessels were actually acquired by the Partnership are retroactively adjusted to include the results of these vessels operated during the periods under common control of Teekay Corporation.

		In June 2008, the Partnership acquired from Teekay Corporation its interest in two 2008-built Aframax lightering tankers, the SPT Explorer and the SPT Navigator . The acquisition included the assumption of debt and Teekay Corporation’s rights and obligations under 10-year, fixed-rate bareboat charters (with options exercisable by the charterer to extend up to an additional five years). The transaction was deemed to be a business acquisition between entities under common control. As a result, the Partnership’s statement of loss for the three months ended March 31, 2008, and the Partnership’s statement of cash flows for the three months ended March 31, 2008, have been retroactively adjusted to include the results of these acquired vessels (referred to herein as the Dropdown Predecessor ), from the date that the Partnership and acquired vessels were both under common control of Teekay Corporation and had begun operations. These vessels began operations on January 7, 2008 ( SPT Explorer) and March 28, 2008 ( SPT Navigator) . The effect of adjusting the Partnership’s financial statements to account for these common control transfers reduced the Partnership’s net loss by $0.5 million for the three months ended March 31, 2008.

		The consolidated financial statements reflect the combined consolidated financial position, results of operations and cash flows of the Partnership and its subsidiaries, including, as applicable, the Dropdown Predecessor.

		Certain of the comparative figures have been reclassified to conform with the presentation adopted in the current period.

		Changes in Accounting Policies

		In December 2007, the Financial Accounting Standards Board (or FASB ) issued SFAS No. 141 (revised 2007), Business Combinations (or SFAS No. 141 (R) ). SFAS No. 141 (R) requires an acquirer to recognize the assets acquired, the liabilities assumed, and any non-controlling interest in the acquiree at the acquisition date, measured at their fair values as of that date. This Statement also requires that the acquirer in a business combination achieved in stages to recognize the identifiable assets and liabilities, as well as the non-controlling interest in the acquiree, at the full fair values of the assets and liabilities as if they had occurred on the acquisition date. In addition, SFAS No. 141 (R) requires that all acquisition related costs be expensed as incurred, rather than capitalized as part of the purchase price and those restructuring costs that an acquirer expected, but was not obligated to incur, to be recognized separately from the business combination. SFAS No. 141 (R) applies prospectively to business combinations for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. The Partnership’s adoption of SFAS No. 141(R) prospectively from January 1, 2009 did not have a material impact on the consolidated financial statements.

Page 7 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES
NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS — (Cont’d)
(all tabular amounts stated in thousands of U.S. dollars, except unit and per unit data)

		In December 2007, the FASB issued SFAS No. 160, Non-controlling Interests in Consolidated Financial Statements — an amendment of ARB No. 51 (SFAS No. 160). SFAS No. 160 amends Accounting Research Bulletin (or ARB ) 51 to establish accounting and reporting standards for the non-controlling (minority) interest in a subsidiary and for the deconsolidation of a subsidiary. This statement provides that non-controlling interests in subsidiaries held by parties other than the partners be identified, labeled and presented in the statement of financial position within equity, but separate from the partners’ equity. SFAS No. 160 states that the amount of consolidated net income (loss) attributable to the partners and to the non-controlling interest be clearly identified on the consolidated statements of income (loss). The statement provides for consistency regarding changes in partners’ ownership including when a subsidiary is deconsolidated. Any retained non-controlling equity investment in the former subsidiary will be initially measured at fair value. On January 1, 2009, the Partnership adopted SFAS No. 160 prospectively. The Partnership has applied the presentation and disclosure provisions of SFAS No. 160 to its consolidated financial statements retrospectively. As a result of the application of SFAS No. 160, the Partnership has reclassified in the Statements of Cash Flows distributions from subsidiaries to non-controlling interests from Operating Activities to Financing Activities.

		In February 2008, the FASB issued FASB Staff Position (or FSP 157-2 ) which delayed the effective date of SFAS No. 157, Fair Value Measurements , for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). For purposes of applying this FSP, nonfinancial assets and nonfinancial liabilities would include all assets and liabilities other than those meeting the definition of a financial asset or financial liability as defined in paragraph 6 of SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities . This FSP defers the effective date of SFAS No. 157 to fiscal years beginning after November 15, 2008, and the interim periods within those fiscal years for items within the scope of this FSP. The Partnership’s adoption of the provisions of SFAS No. 157 related to those items covered by FSP 157-2 from January 1, 2009 did not have a material impact on the Partnership’s consolidated financial statements.

		In March 2008, the FASB issued SFAS No. 161, Disclosures About Derivative Instruments and Hedging Activities — an amendment of FASB Statement No. 133 (or SFAS No. 161 ), which requires expanded disclosures about a company’s derivative instruments and hedging activities, including increased qualitative, and credit-risk disclosures to enable investors to better understand how these instruments and activities are accounted for; how and why they are used; and their effects on an entity’s financial position, financial performance, and cash flows. SFAS No. 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early adoption permitted. On January 1, 2009, the Partnership adopted the provisions of SFAS No. 161. See Note 8 of the notes to the consolidated financial statements.

		In March 2008, the FASB issued its final consensus on the Emerging Issues Task Force (or EITF ) Issue 07-4, Application of the Two-Class Method under FASB Statement No. 128, Earnings per Share, to Master Limited Partnerships . This issue may impact a publicly traded master limited partnership (or MLP ) that distributes “available cash”, as defined in the respective partnership agreements, to limited partners (or LPs ), the general partner (or GP ), and the holders of incentive distribution rights ( or IDRs ). This issue addresses earnings-per-unit (or EPU ) computations for all MLPs with IDR interests. MLPs will need to determine the amount of “available cash” at the end of the reporting period when calculating the period’s EPU. This guidance in Issue 07-4 is effective for the Partnership for the fiscal year beginning January 1, 2009 and is applied retrospectively to all periods presented. On January 1, 2009, the Partnership adopted the provisions of Issue 07-4. See Note 12 of the notes to the consolidated financial statements.

		In April 2008, FASB issued FASB Staff Position No. 142-3 (or FSP No. 142-3 ), Determination of the Useful Life of Intangible Assets . This FSP amends the factors that should be considered in developing renewal or extension of assumptions used to determine the useful life of a recognized intangible asset under SFAS No. 142, Goodwill and Other Intangible Assets . This FSP is effective for the Partnership for fiscal years beginning after December 15, 2008, and interim periods within those fiscal years. Early adoption is prohibited. The adoption of FSP 142-3 did not have a material impact on the Partnership’s consolidated financial statements.

2.		Fair Value of Measurements

		SFAS No. 157 clarifies the definition of fair value, prescribes methods for measuring fair value, establishes a fair value hierarchy based on the inputs used to measure fair value and expands disclosure about the use of fair value measurements. The fair value hierarchy has three levels based on the reliability of the inputs used to determine fair value as follows:

Level 1.		Observable inputs such as quoted prices in active markets;

Level 2.		Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and

Level 3.		Unobservable inputs in which there is little or no market data, which require the reporting entity to develop its own assumptions.

The following table presents the Partnership’s assets and liabilities that are measured at fair value on a recurring basis and are categorized using the fair value hierarchy.


	Fair Value at March 31,
	2009 Liability			Level 1		Level 2			Level 3
	$			$		$			$
Interest rate swap agreements ^{(1) , (2)}		(137,459	)		—		(137,459	)		—
Foreign currency forward contracts ⁽¹⁾		(25,435	)		—		(25,435	)		—

		(162,894	)		—		(162,894	)		—

Page 8 of 27

(1)

The fair value of the Partnership’s derivative agreements is the estimated amount that the Partnership would receive or pay to terminate the agreements at the reporting date, taking into account current interest rates, foreign exchange rates and the current credit worthiness of both the Partnership and the swap counterparties. The estimated amount is the present value of future cash flows. Given the current volatility in the credit markets, it is reasonably possible that the amount recorded as a derivative liability could vary by a material amount in the near term.

(2)

The fair value of the Partnership’s interest rate swap agreements includes $8.4 million of accrued interest which is recorded in accrued liabilities on the balance sheet.

		The Partnership has determined that there are no non-financial assets or non-financial liabilities carried at fair value at March 31, 2009.

3.		Segment Reporting

		The Partnership is engaged in the international marine transportation of crude oil through the operation of its oil tankers and floating storage and off-take (or FSO ) units. The Partnership’s revenues are earned in international markets.

		The Partnership has three reportable segments: its shuttle tanker segment; its conventional tanker segment; and its FSO segment. The Partnership’s shuttle tanker segment consists of shuttle tankers operating primarily on fixed-rate contracts of affreightment, time-charter contracts or bareboat charter contracts. The Partnership’s conventional tanker segment consists of conventional tankers operating on fixed-rate, time-charter contracts or bareboat charter contracts. The Partnership’s FSO segment consists of its FSO units subject to fixed-rate, time-charter contracts or bareboat charter contracts. Segment results are evaluated based on income from vessel operations. The accounting policies applied to the reportable segments are the same as those used in the preparation of the Partnership’s consolidated financial statements.

		The following tables include results for these segments from continuing operations for the periods presented in these consolidated financial statements.


	Three Months Ended March 31,
	2009								2008
	Shuttle		Conventional						Shuttle		Conventional
	Tanker		Tanker		FSO				Tanker		Tanker		FSO
	Segment		Segment		Segment		Total		Segment		Segment		Segment		Total
	$		$		$		$		$		$		$		$
Voyage revenues		138,135		30,201		15,089		183,425		153,059		34,827		17,046		204,932
Voyage expenses		18,238		6,339		236		24,813		38,553		12,476		348		51,377
Vessel operating expenses		39,522		5,390		5,822		50,734		29,660		5,959		6,312		41,931
Time-charter hire expense		32,145		—		—		32,145		33,646		—		—		33,646
Depreciation and amortization		23,155		5,974		5,402		34,531		22,551		5,257		5,104		32,912
General and administrative ⁽¹⁾		10,048		1,434		440		11,922		12,793		2,204		829		15,826
Restructuring charges		2,201		—		—		2,201		—		—		—		—

Income from vessel operations		12,826		11,064		3,189		27,079		15,856		8,931		4,453		29,240


(1)		Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to each segment based on estimated use of corporate resources).

Page 9 of 27

A reconciliation of total segment assets to total assets presented in the accompanying consolidated balance sheets is as follows:


	March 31,		December 31,
	2009		2008
	$		$
Shuttle tanker segment		1,494,206		1,517,961
Conventional tanker segment		326,592		332,795
FSO segment		102,742		108,304
Unallocated:
Cash and cash equivalents		147,837		131,488
Accounts receivable and other assets		80,813		89,544

Consolidated total assets		2,152,190		2,180,092

4.		Intangible Assets

		As at March 31, 2009 and December 31, 2008, intangible assets consisted of:


	March 31,			December 31,
	2009			2008
	$			$
Gross carrying amount		124,250			124,250
Accumulated amortization		(81,224	)		(78,960	)

Net carrying amount		43,026			45,290

		Aggregate amortization expense of intangible assets for the three months ended March 31, 2009 was $2.3 million ($2.5 million – 2008). Amortization of intangible assets for the next five years subsequent to March 31, 2009 is expected to be $6.8 million (remainder of 2009), $8.1 million (2010), $7.0 million (2011), $6.0 million (2012), and $5.0 million (2013).

5.		Long-Term Debt


	March 31, 2009		December 31, 2008
	$		$
U.S. Dollar-denominated Revolving Credit Facilities due through 2018		1,305,553		1,314,264
U.S. Dollar-denominated Term Loans due through 2017		248,701		252,172

		1,554,254		1,566,436
Less current portion		118,598		125,503

Total		1,435,656		1,440,933

As at March 31, 2009, the Partnership had seven long-term revolving credit facilities (collectively, the Revolvers ), which, as at such date, provided for borrowings of up to $1.45 billion, of which $147.7 million was undrawn. The total amount available under the revolving credit facilities reduces by $122.4 million (remainder of 2009), $132.8 million (2010), $140.0 million (2011), $147.6 million (2012), $169.6 million (2013) and $740.9 million (thereafter). Five of the revolving credit facilities are guaranteed by certain subsidiaries of the Partnership for all outstanding amounts and contain covenants that require Teekay Offshore Operating L.P. (or OPCO ) to maintain the greater of a minimum liquidity (cash, cash equivalents and undrawn committed revolving credit lines with at least six months to maturity) of at least $75.0 million and 5.0% of OPCO’s total consolidated debt. The remaining revolving credit facilities are guaranteed by Teekay Corporation and contain covenants that require Teekay Corporation to maintain the greater of a minimum liquidity of at least $50.0 million and 5.0% of Teekay Corporation’s total consolidated debt which has recourse to Teekay Corporation. The revolving credit facilities are collateralized by first-priority mortgages granted on 33 of the Partnership’s vessels, together with other related security.

As at March 31, 2009, five of the Partnership’s six 50%-owned subsidiaries each had an outstanding term loan, which in the aggregate totaled $248.7 million. The term loans have varying maturities through 2017 and semi-annual payments that reduce over time. All term loans are collateralized by first-priority mortgages on the vessels to which the loans relate, together with other related security. As at March 31, 2009, the Partnership had guaranteed $74.2 million of these term loans, which represents its 50% share of the outstanding vessel mortgage debt of four of these 50%-owned subsidiaries. The other owner and Teekay Corporation have guaranteed the remaining $174.5 million.

Page 10 of 27

		Interest payments on the revolving credit facilities and the term loans are based on LIBOR plus a margin. At March 31, 2009 and December 31, 2008, the margins ranged between 0.45% and 0.95%. The weighted-average effective interest rate on the Partnership’s long-term debt as at March 31, 2009 was 2.3% (December 31, 2008 – 3.4%). This rate does not include the effect of the Partnership’s interest rate swaps (Note 8).

		The aggregate annual long-term debt principal repayments required to be made subsequent to March 31, 2009 are $113.3 million (remainder of 2009), $134.7 million (2010), $169.3 million (2011), $147.1 million (2012), $155.5 million (2013), and $834.4 million (thereafter).

6.		Restructuring Charge and Other Income – Net

Restructuring Charge

During the three months ended March 31, 2009, the Partnership commenced the reflagging of seven of its vessels from Norwegian flag to Bahamian flag and changing the nationality mix of its crews. Under this plan, the Partnership expects to record and pay restructuring charges consisting mainly of one-time termination benefits of approximately $4.4 million during 2009. During the three months ended March 31, 2009, the Partnership incurred $2.2 million of restructuring costs.

Other Income


	Three Months Ended March 31,
	2009		2008
	$		$
Volatile organic compound emissions plant lease income		1,962		2,570
Miscellaneous		1,119		772

Other income — net		3,081		3,342

Related Party Transactions and Balances

Nine of OPCO’s conventional tankers are employed on long-term time-charter contracts with a subsidiary of Teekay Corporation. Under the terms of eight of these nine time-charter contracts, OPCO is responsible for the bunker fuel expenses; however, OPCO adds the approximate amounts of these expenses to the daily hire rate plus a 4.5% margin. Pursuant to these time-charter contracts, OPCO earned voyage revenues of $27.8 million and $33.7 million during the three months ended March 31, 2009 and 2008, respectively.

Two of OPCO’s shuttle tankers are employed on long-term bareboat charters with a subsidiary of Teekay Corporation. Pursuant to these charter contracts, OPCO earned voyage revenues of $3.1 million and $3.5 million during the three months ended March 31, 2009 and 2008, respectively.

Two of OPCO’s FSO units are employed on long-term bareboat charters with a subsidiary of Teekay Corporation. Pursuant to these charter contracts, OPCO earned voyage revenues of $2.8 million during the both three months ended March 31, 2009 and 2008, respectively.

A subsidiary of Teekay Corporation has entered into a services agreement with a subsidiary of OPCO, pursuant to which the subsidiary of OPCO provides the Teekay Corporation subsidiary with ship management services. Pursuant to this agreement, OPCO earned management fees of $0.8 million during both the three months ended March 31, 2009 and 2008, respectively.

Eight of OPCO’S Aframax conventional oil tankers and two FSO units are managed by subsidiaries of Teekay Corporation. Pursuant to the associated management services agreements, the Partnership incurred general and administrative expenses of $0.9 million and $1.4 million during the three months ended March 31, 2009 and March 31, 2008, respectively.

The Partnership, OPCO and certain of OPCO’s operating subsidiaries have entered into services agreements with certain subsidiaries of Teekay Corporation in connection with the Partnership’s initial public offering, pursuant to which Teekay Corporation subsidiaries provide the Partnership, OPCO and its operating subsidiaries with administrative, advisory and technical services and ship management services. Pursuant to these service agreements, the Partnership incurred $9.6 million and $12.1 million of these costs during the three months ended March 31, 2009 and March 31, 2008, respectively.

Pursuant to the Partnership’s partnership agreement, the Partnership reimburses the General Partner for all expenses incurred by the Partnership that are necessary or appropriate for the conduct of the Partnership’s business. The Partnership incurred $0.1 million of these costs during both the three months ended March 31, 2009 and March 31, 2008, respectively.

The Partnership has entered into an omnibus agreement with Teekay Corporation, Teekay LNG Partners L.P., the General Partner and others governing, among other things, when the Partnership, Teekay Corporation and Teekay LNG Partners L.P. may compete with each other and certain rights of first offering on liquefied natural gas carriers, oil tankers, shuttle tankers, FSO units and floating production, storage and offloading units.

Page 11 of 27

In March 2008, Teekay Corporation agreed to reimburse the Partnership for repair costs relating to one of the Partnership’s shuttle tankers. The vessel was purchased from Teekay Corporation in July 2007 and had, as of the date of acquisition, an inherent minor defect that required repairs. Pursuant to this agreement, Teekay Corporation reimbursed $0.4 million of these costs during the three months ended March 31, 2008.

In March 2008, a subsidiary of OPCO sold certain vessel equipment to a subsidiary of Teekay Corporation for proceeds equal to its net book value of $1.4 million.

In December 2008, OPCO entered into a bareboat charter contract to in-charter one shuttle tanker from a subsidiary of Teekay Corporation. Pursuant to the charter contract, OPCO incurred time-charter hire expenses of $1.8 million during the three months ended March 31, 2009.

At March 31, 2009, due from affiliates totaled $11.2 million (December 31, 2008 — $10.1 million) and due to affiliates totaled $11.7 million (December 31, 2008 — $8.7 million). Due to and from affiliate are non-interest bearing and unsecured.

Derivative Instruments and Hedging Activities

The Partnership uses derivatives in accordance with its overall risk management policies. The following summarizes the Partnership’s risk strategies with respect to market risk from foreign currency fluctuations and changes in interest rates.

The Partnership hedges portions of its forecasted expenditures denominated in foreign currencies with foreign currency forward contracts. These foreign currency forward contracts are generally designated, for accounting purposes, as cash flow hedges of forecasted foreign currency expenditures. Where such instruments are designated and qualify as cash flow hedges, the effective portion of the changes in their fair value is recorded in accumulated other comprehensive income (loss), until the hedged item is recognized in earnings. At such time, the respective amount in accumulated other comprehensive income (loss) is released to earnings and is recorded within operating expenses, based on the nature of the expense. The ineffective portion of these foreign currency forward contracts has also been reported in operating expenses, based on the nature of the expense.

During the three months ended March 31, 2009 and 2008, the Partnership recognized the following realized and unrealized gains (losses) relating to foreign currency forward contracts that are designated as cash flow hedges for accounting:


	Three Months Ended			Three Months Ended
	March 31, 2009			March 31, 2008
	$			$
Gains (losses) recognized in:
Vessel operating expenses		(3,718	)		(207	)
General and administrative		236			(231	)
Foreign currency exchange loss		—			452
Accumulated other comprehensive income		2,360			3,181
(Gains) losses reclassified from:
Accumulated other comprehensive income		5,556			(704	)

Realized and unrealized gains (losses) of foreign currency forward contracts that are not designated for accounting purposes as cash flow hedges, are recognized in earnings and reported in realized and unrealized gains (losses) on non-designated derivatives in the consolidated statements of income (loss). During the three months ended March 31, 2009 and 2008, the Partnership recognized net realized and unrealized gains (losses) on foreign currency forward contracts of ($0.6) million and $0.5 million, respectively. The realized and unrealized gain of $0.5 million relating to foreign currency forwards contracts for the three months ended March 31, 2008 was reclassified from general and administrative expenses to realized and unrealized gains (losses) on non-designated derivatives for comparative purposes.

As at March 31, 2009, the Partnership was committed to the following foreign currency forward contracts:


			Fair Value / Carrying		Average
	Contract Amount in		Amount		Forward		Expected Maturity
	Foreign Currency		of Liability		Rate ⁽¹⁾		2009		2010
	(thousands)		(thousands of U.S. Dollars)				(in thousands of U.S. Dollars)
Norwegian Kroner		1,044,561	$	22,764		5.89	$	81,426	$	96,068
Australian Dollar		2,819		573		1.12		2,516		—
British Pound		273		128		0.52		422		99
Euro		18,750		1,970		0.70		14,624		12,254

			$	25,435			$	98,988	$	108,421


(1)		Average forward rate represents the contracted amount of foreign currency one U.S. Dollar will buy.

Page 12 of 27

As at March 31, 2009, the Partnership’s accumulated other comprehensive loss included $13.1 million of unrealized losses on foreign currency forward contracts designated as cash flow hedges.

The Partnership enters into interest rate swaps, which exchange a receipt of floating interest for a payment of fixed interest to reduce the Partnership’s exposure to interest rate variability on its outstanding floating-rate debt. The Partnership has not designated, for accounting purposes, its interest rate swaps as cash flow hedges of its USD LIBOR denominated borrowings. Realized and unrealized gains (losses) relating to the Partnership’s interest rate swaps have been reported in realized and unrealized gains (losses) on non-designated derivatives in the consolidated statements of income (loss). During the three months ended March 31, 2009 and 2008, the Partnership recognized net realized and unrealized gains (losses) of $18.2 million and ($45.9) million relating to its interest rate swaps. The realized and unrealized loss of ($45.9) million relating to interest rate swaps for the three months ended March 31, 2008 was reclassified from interest expense to realized and unrealized gain on non-designated derivatives for comparative purposes.

As at March 31, 2009, the Partnership was committed to the following interest rate swap agreements:

Fair Value /

Carrying

Fixed

Interest

Principal

Amount of

Weighted-Average

Interest

Rate

Amount

Liability ⁽³⁾

Remaining Term

Rate

Index

(Years)

(%) ⁽¹⁾

U.S. Dollar-denominated interest rate swaps

LIBOR

735,000

75,225

6.7

4.8

U.S. Dollar-denominated interest rate swaps ⁽²⁾

LIBOR

396,266

62,234

12.1

5.0

1,131,266

137,459


(1)		Excludes the margin the Partnership pays on its variable-rate debt, which as at March 31, 2009 ranged from 0.45% and 0.95%.

(2)		Principal amount reduces quarterly or semi-annually.

(3)		The fair value of the Partnership’s interest rate swap agreements includes $8.4 million of accrued interest which is recorded in accrued liabilities on the balance sheet.

The Partnership is exposed to credit loss in the event of non-performance by the counterparties to the foreign currency forward contracts and the interest rate swap agreements. In order to minimize counterparty risk, the Partnership only enters into derivative transactions with counterparties that are rated A or better by Standard & Poor’s or Aa3 or better by Moody’s at the time of the transactions. In addition, to the extent possible and practical, interest rate swaps are entered into with different counterparties to reduce concentration risk.

9.		Income Tax Expense

		The components of the provision for income tax expense are as follows:


	Three Months Ended March 31,
	2009			2008
	$			$
Current		(58	)		—
Deferred		(4,080	)		(913	)

Income tax expense		(4,138	)		(913	)

10.		Commitments and Contingencies

		The Partnership may, from time to time, be involved in legal proceedings and claims that arise in the ordinary course of business. The Partnership believes that any adverse outcome, individually or in the aggregate, of any existing claims would not have a material affect on its financial position, results of operations or cash flows, when taking into account its insurance coverage and indemnifications from charterers or Teekay Corporation.

11.		Vessel and Equipment Sales

		During 2008, a subsidiary of OPCO sold certain vessel equipment to a subsidiary of Teekay Corporation for proceeds equal to its net book value of $1.4 million.

12.		Partners’ Equity and Net Income (Loss) Per Unit

		At March 31, 2009, of our total limited partner units outstanding, 51.03% were held by the public and the remaining units were held by a subsidiary of Teekay Corporation.

Page 13 of 27

Limited Partners’ Rights

Significant rights of the limited partners include the following:

•

Right to receive distribution of available cash within approximately 45 days after the end of each quarter.

•

No limited partner shall have any management power over the Partnership’s business and affairs; the general partner shall conduct, direct and manage our activities.

•

The General Partner may be removed if such removal is approved by unitholders holding at least 66 2/3% of the outstanding units voting as a single class, including units held by the General Partner and its affiliates.

Subordinated Units

All of the Partnership’s subordinated units are held by a subsidiary of Teekay Corporation. Under the partnership agreement, during the subordination period applicable to the Partnership’s subordinated units, the common units will have the right to receive distributions of available cash from operating surplus in an amount equal to the minimum quarterly distribution of $0.35 per quarter, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. Distribution arrearages do not accrue on the subordinated units. The purpose of the subordinated units is to increase the likelihood that during the subordination period there will be available cash to be distributed on the common units.

The subordination period will extend until the first day of any quarter beginning after December 31, 2009. Thereafter the subordination period will terminate automatically and the subordinated units will convert into common units on a one–for-one basis if certain tests are met.

For the purposes of the net income per unit calculation as defined below, during the quarter ended March 31, 2009, cash available for distribution exceeded the minimum quarterly distribution of $0.35 per unit and, consequently, the assumed distribution of net income did not result in an unequal distribution of net income between the subordinated unit holders and common unit holders for the purposes of the net income per unit calculation as defined below. During the quarter ended March 31, 2008, the Partnership incurred a net loss and, consequently, the assumed distributions of net loss resulted in equal distributions of net loss between the subordinated unit holders and common unit holders.

Incentive Distribution Rights

The General Partner is entitled to incentive distributions if the amount the Partnership distributes to unitholders with respect to any quarter exceeds specified target levels shown below:


Quarterly Distribution Target Amount (per unit)	Unitholders			General Partner
Minimum quarterly distribution of $0.35		98	%		2	%
Up to $0.4025		98	%		2	%
Above $0.4025 up to $0.4375		85	%		15	%
Above $0.4375 up to $0.525		75	%		25	%
Above $0.525		50	%		50	%

During the quarter ended March 31, 2009, cash available for distribution exceeded $0.4025 per unit and, consequently, the assumed distribution of net income resulted in the use of the increasing percentages to calculate the General Partner’s interest in net income for the purposes of the net income per unit calculation. During the quarter ended March 31, 2008 cash available for distribution did not exceed $0.4025 per unit and, consequently, the assumed distributions of net loss did not result in the use of the increasing percentages to calculate the General Partner’s interest in cash available for distribution for the purposes of the net loss per unit calculation.

In the event of a liquidation, all property and cash in excess of that required to discharge all liabilities will be distributed to the unitholders and our general partner in proportion to their capital account balances, as adjusted to reflect any gain or loss upon the sale or other disposition of the Partnership’s assets in liquidation in accordance with the partnership agreement.

Net Income (Loss) Per Unit

Net income (loss) per unit is determined by dividing net income (loss), after deducting the amount of net income (loss) attributable to the Dropdown Predecessor, the non-controlling interest and the General Partner’s interest, by the weighted-average number of units outstanding during the applicable period.

Page 14 of 27

As required by Emerging Issues Task Force Issue No. 03-6, Participating Securities and Two-Class Method under FASB Statement No. 128, Earnings Per Share, the interests of the General Partner, common unit holders and subordinated unitholders in net income are calculated as if all net income was distributed according to the terms of the Partnership’s partnership agreement, regardless of whether those earnings would or could be distributed. The partnership agreement does not provide for the distribution of net income; rather, it provides for the distribution of available cash, which is a contractually defined term that generally means all cash on hand at the end of each quarter less the amount of cash reserves established by the Partnership’s board of directors to provide for the proper conduct of the Partnerships’ business including reserves for maintenance and replacement capital expenditure and anticipated credit needs. Unlike available cash, net income is affected by non-cash items such as depreciation and amortization, unrealized gains and losses on derivative instruments and foreign currency translation gains (losses).

The calculations of the basic and diluted earnings per unit are presented below.


	Three Months ended March 31,
	2009		2008
	$		$
Net income (loss) attributable to Teekay Offshore Partners L.P.		16,940		(13,234	)
Net income (loss) attributable to:
Common unit holders		11,031		(6,484	)
Subordinated unit holders		5,293		(6,485	)
General partner interest		616		(265	)
Weighted average units outstanding (Basic and diluted)
Common unit holders		20,425,000		9,800,000
Subordinated unit holders		9,800,000		9,800,000
Net income (loss) per unit (Basic and diluted)
Common unit holders		0.54		(0.66	)
Subordinated unit holders		0.54		(0.66	)

Pursuant to the partnership agreement, allocations are made to partners on a quarterly basis.

13.		Supplemental Cash Flow Information

		The Partnership’s consolidated statement of cash flows for the three months ended March 31, 2008 reflects the Dropdown Predecessor as if the Partnership had acquired the Dropdown Predecessor when each respective vessel began operations under the ownership of Teekay Corporation. If Teekay Corporation financed the construction or purchase of the vessel prior to the Dropdown Predecessor being included in the results of the Partnership, the expenditures for the vessel by Teekay Corporation have been treated as a non-cash transaction in the Partnership’s consolidated statement of cash flows. The non-cash investing activities related to the Dropdown Predecessor were $90.5 million for expenditures for vessels and equipment in the three months ended March 31, 2008.

14.		Recent Accounting Pronouncements

		In June 2009, FASB issued SFAS No. 168, The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles – a replacement of FASB Statement No. 162 (or SFAS No. 168 ). SFAS No. 168 identifies the source of authoritative GAAP recognized by the FASB to be applied by nongovernmental entities. Rules and interpretive releases of the Securities and Exchange Commission (or SEC ) under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants. On the effective date of this Statement, the Codification will supersede all then-existing non-SEC accounting and reporting standards. All other non-grandfathered non-SEC accounting literature not included in the Codification will become non-authoritative. This statement is effective for financial statements issued for interim and annual periods ending after September 15, 2009. The Partnership is currently assessing the potential impacts, if any, on its consolidated financial statements.

		In June 2009, FASB issued SFAS No. 167, Amendments to FASB Interpretation No. 46(R) (or SFAS No. 167 ). SFAS No. 167 eliminates FASB Interpretation 46(R)’s exceptions to consolidating qualifying special-purpose entities, contains new criteria for determining the primary beneficiary, and increases the frequency of required reassessments to determine whether a company is the primary beneficiary of a variable interest entity. SFAS No. 167 also contains a new requirement that any term, transaction, or arrangement that does not have a substantive effect on an entity’s status as a variable interest entity, a company’s power over a variable interest entity, or a company’s obligation to absorb losses or its right to receive benefits of an entity must be disregarded in applying FASB Interpretation 46(R)’s provisions. The elimination of the qualifying special-purpose entity concept and its consolidation exceptions means more entities will be subject to consolidation assessments and reassessments. SFAS No. 167 is effective for fiscal years beginning after November 15, 2009, and for interim periods within that first period, with earlier adoption prohibited. The Partnership is currently assessing the potential impacts, if any, on its consolidated financial statements.

Page 15 of 27

In June 2009, the FASB issued SFAS No. 166, Accounting for Transfers of Financial Assets — an amendment of FASB Statement No. 140 (or SFAS No. 166 ). SFAS No. 166 eliminates the concept of a qualifying special-purpose entity, creates more stringent conditions for reporting a transfer of a portion of a financial asset as a sale, clarifies other sale-accounting criteria, and changes the initial measurement of a transferor’s interest in transferred financial assets. SFAS No. 166 will be effective for transfers of financial assets in fiscal years beginning after November 15, 2009, and in interim periods within those fiscal years with earlier adoption prohibited. The Partnership is currently assessing the potential impacts, if any, on its consolidated financial statements.

In May 2009, the FASB issued SFAS No. 165, Subsequent Events (or SFAS No. 165 ). SFAS No. 165 is intended to establish general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. It requires the disclosure of the date through which an entity has evaluated subsequent events and the basis for selecting that date, that is, whether that date represents the date the financial statements were issued or were available to be issued. SFAS No. 165 is for interim and annual reporting periods ending after June 15, 2009. The Partnership is evaluating the impact, if any, SFAS No. 165 will have on its consolidated financial statements.

In April 2009, the FASB issued FSP No. 107-1 and APB 28-1, which extends the requirements of SFAS No. 107, Disclosures about Fair Value of Financial Instruments (SFAS No. 107) to interim financial statements of publicly-traded companies. Prior to FSP No. FAS 107-1 and APB 28-1, fair values for these assets and liabilities were only disclosed once a year. FSP No. FAS 107-1 and APB 28-1 requires that disclosures provide qualitative and quantitative information on fair value estimates for all financial instruments not measured on the balance sheet at fair value, when practicable, with the exception of certain financial instruments listed in SFAS No. 107. FSP No. FAS 107-1 and APB 28-1 is effective prospectively for interim reporting periods ending after June 15, 2009. The Partnership is evaluating the impact, if any, FSP No. FAS 107-1 and APB 28-1 will have on its consolidated financial statements.

15.

Subsequent events

In July 2009, the Partnership declared a cash distribution of $0.45 per unit for the quarter ended June 30, 2009. The cash distribution will be paid on August 14, 2009 to all unitholders of record on July 29, 2009.

During June and July 2009, the Partnership entered into agreements for two term loans relating to two of its 50%-owned shuttle tankers for $35.7 million and $35 million, respectively.

Page 16 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES
MARCH 31, 2009
PART I — FINANCIAL INFORMATION

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

OVERVIEW

We are an international provider of marine transportation and storage services to the offshore oil industry. We were formed in August 2006 by Teekay Corporation, a leading provider of marine services to the global oil and natural gas industries, to further develop its operations in the offshore market. Our principal asset is a 51% controlling interest in Teekay Offshore Operating L.P. (or OPCO ), which operates a substantial majority of our shuttle tankers and floating storage and offtake (or FSO ) units and all of our conventional crude oil tankers. Our growth strategy focuses on expanding our fleet of shuttle tankers and FSO units under long-term, fixed-rate time charters. We intend to continue our practice of acquiring shuttle tankers and FSO units as needed for approved projects only after the long-term charters for the projects have been awarded to us, rather than ordering vessels on a speculative basis. We intend to follow this same practice in acquiring floating production, storage and offloading (or FPSO ) units, which produce and process oil offshore in addition to providing storage and offloading capabilities. We seek to capitalize on opportunities emerging from the global expansion of the offshore transportation, storage and production sectors by selectively targeting long-term, fixed-rate time charters. We may enter into joint ventures and partnerships with companies that may provide increased access to these opportunities or may engage in vessel or business acquisitions. We seek to leverage the expertise, relationships and reputation of Teekay Corporation and its affiliates to pursue these growth opportunities in the offshore sectors and may consider other opportunities to which our competitive strengths are well suited. We view our conventional tanker fleet primarily as a source of stable cash flow as we seek to expand our offshore operations.

SIGNIFICANT DEVELOPMENTS

Potential Additional Shuttle Tanker, FSO and FPSO Projects

Pursuant to an omnibus agreement we entered into in connection with our initial public offering in December 2006, Teekay Corporation is obligated to offer us its interest in certain shuttle tankers, FSO units, FPSO units and joint ventures it may acquire in the future, provided the vessels are servicing contracts in excess of three years in length.

Pursuant to the omnibus agreement, Teekay Corporation was also obligated to offer to us the FPSO unit, the Varg , within 30 days of the unit being re-chartered by Teekay Corporation’s wholly-owned subsidiary, Teekay Petrojarl AS (or Teekay Petrojarl) on December 4, 2008. We have agreed to waive Teekay Corporation’s obligation to offer the unit to us for charter or purchase within 30 days of the re-chartering in exchange for the right to acquire the unit, for its fair market value, at any time until December 4, 2009.

The omnibus agreement also obligated Teekay Corporation to offer to us prior to July 9, 2009, existing FPSO units of Teekay Petrojarl that were servicing contracts in excess of three years in length as of July 9, 2008, the date on which Teekay Corporation acquired 100% of Teekay Petrojarl. We have agreed to waive Teekay Corporation’s obligation to offer these FPSO units to us by July 9, 2009 in exchange for the right to acquire these units, for their fair market value, at any time until July 9, 2010. The purchase price for any such existing FPSO units of Teekay Petrojarl would be their fair market value plus any additional tax or other similar costs to Teekay Petrojarl that would be required to transfer the offshore vessels to us.

In addition, Teekay Corporation has ordered four Aframax shuttle tanker newbuildings, which are scheduled to deliver in 2010 and 2011, for a total delivered cost of approximately $460 million. It is anticipated that these vessels will be offered to us and will be used to service either new long-term, fixed-rate contracts Teekay Corporation may be awarded prior to the vessel deliveries or OPCO’s contracts-of-affreightment in the North Sea.

We also may acquire additional limited partner interests in OPCO or other vessels that Teekay Corporation may offer us from time to time in the future.

RESULTS OF OPERATIONS

We use a variety of financial and operational terms and concepts when analyzing our results of operations, which can be found in Item 5. Operating and Financial Review and Prospects in our Annual Report on Form 20-F for the year ended December 31, 2008. In accordance with United States generally accepted accounting principles (or GAAP ), we report gross revenues in our income statements and include voyage expenses among our operating expenses. However, shipowners base economic decisions regarding the deployment of their vessels upon anticipated time charter equivalent (or TCE ) rates, and industry analysts typically measure bulk shipping freight rates in terms of TCE rates. This is because under time charters and bareboat charters the customer usually pays the voyage expenses, while under voyage charters and contracts of affreightment the shipowner usually pays the voyage expenses, which typically are added to the hire rate at an approximate cost. Accordingly, the discussion of revenue below focuses on net voyage revenues (i.e. voyage revenues less voyage expenses) and TCE rates of our three reportable segments where applicable. TCE rates represent net voyage revenues divided by revenue days. Please read Item 1 — Financial Statements: Note 3 — Segment Reporting.

Page 17 of 27

Items You Should Consider When Evaluating Our Results of Operations

You should consider the following factors when evaluating our historical financial performance and assessing our future prospects:

•

Our financial results reflect the results of the interests in vessels acquired from Teekay Corporation for all periods the vessels were under common control. In June 2008, we acquired from Teekay Corporation its interests in two 2008-built Aframax tankers, the SPT Explorer and the SPT Navigator. This acquisition included the assumption of debt and Teekay Corporation’s rights and obligations under the 10-year, fixed-rate bareboat charters (with options exercisable by the charterer to extend up to an additional five years). This transaction was deemed to be a business acquisition between entities under common control. Accordingly, we have accounted for this transaction in a manner similar to the pooling of interest method. Under this method of accounting, our financial statements prior to the date the interests in these vessels were actually acquired by us are retroactively adjusted to include the results of the acquired vessels. The periods retroactively adjusted include all periods that we and the acquired vessel were both under common control of Teekay Corporation and had begun operations. As a result, our statement of income (loss) for the three months ended March 31, 2008 reflect the vessels, referred to herein as the Dropdown Predecessor , as if we had acquired them when the vessels began operations under the ownership of Teekay Corporation. These vessels began operations on January 7, 2008 ( SPT Explorer) and March 28, 2008 ( SPT Navigator) .

•

The size of our fleet continues to change. Our results of operations reflect changes in the size and composition of our fleet due to certain vessel deliveries and vessel dispositions. For instance, the average number of owned vessels in our conventional tanker segment increased from 10 in 2008 to 11 in 2009. Please read “— Results of Operations” below for further details about vessel dispositions and deliveries. Due to the nature of our business, we expect our fleet to continue to fluctuate in size and composition.

•

Our vessel operating costs are facing industry-wide cost pressures . The shipping industry is experiencing a global manpower shortage due to significant growth in the world fleet. This shortage has resulted in crewing wage increases during 2007 and 2008, and has continued to date during 2009.

•

Our financial results of operations are affected by fluctuations in currency exchange rates . Under GAAP, all foreign currency-denominated monetary assets and liabilities, such as cash and cash equivalents, accounts receivable, accounts payable, advances from affiliates and deferred income taxes are revalued and reported based on the prevailing exchange rate at the end of the period. OPCO has entered into services agreements with subsidiaries of Teekay Corporation whereby the subsidiaries operate and crew the vessels. Beginning in 2009, payments under the service agreements have been adjusted to reflect any change in Teekay Corporation’s cost of providing services based on fluctuations in the value of the Norwegian Kroner relative to the U.S. Dollar, which may result in increased payments under the services agreements if the strength of the U.S. Dollar declines relative to the Norwegian Kroner.

•

Our net income (loss) is affected by fluctuations in the fair value of our derivatives . Our interest rate swaps and some of our foreign currency forward contracts are not designated as hedges for accounting purposes. Although we believe these derivative instruments are economic hedges, the changes in their fair value are included in our statements of income (loss) as unrealized gains or losses on non-designated derivatives. The changes in fair value do not affect our cash flows, liquidity or cash distributions to partners.

•

Our operations are seasonal. Historically, the utilization of shuttle tankers in the North Sea is higher in the winter months, as favorable weather conditions in the warmer months provide opportunities for repairs and maintenance to our vessels and to the offshore oil platforms. Downtime for repairs and maintenance generally reduces oil production and, thus, transportation requirements. 12 vessels are scheduled for drydocking in 2009.

We manage our business and analyze and report our results of operations on the basis of three business segments: the shuttle tanker segment, the conventional tanker segment and the FSO segment.

Shuttle Tanker Segment

Our shuttle tanker fleet consists of 37 vessels that operate under fixed-rate contracts of affreightment, time charters and bareboat charters. Of the 37 shuttle tankers, 25 are owned by OPCO (including 5 through 50% owned subsidiaries), 10 are chartered-in by OPCO and 2 are owned by us (including one through a 50% owned subsidiary). All of these shuttle tankers provide transportation services to energy companies, primarily in the North Sea and Brazil. Our shuttle tankers service the conventional spot market from time to time where spot rates during 2009 have experienced significant declines compared to 2008 as a result of the contraction in the global economy.

The following table presents our shuttle tanker segment’s operating results for the three months ended March 31, 2009 and 2008, and compares its net voyage revenues (which is a non-GAAP financial measure) for the three months ended March 31, 2009 and 2008 to voyage revenues, the most directly comparable GAAP financial measure, for the same periods. The following table also provides a summary of the changes in calendar-ship-days by owned and chartered-in vessels for our shuttle tanker segment:


	Three Months Ended March 31,
(in thousands of U.S. dollars, except calendar-ship-days and percentages)	2009		2008		% Change
Voyage revenues		138,135		153,059		(9.8	)
Voyage expenses		18,238		38,553		(52.7	)

Net voyage revenues		119,897		114,506		4.7
Vessel operating expenses		39,522		29,660		33.3
Time-charter hire expense		32,145		33,646		(4.5	)
Depreciation and amortization		23,155		22,551		2.7
General and administrative ⁽¹⁾		10,048		12,793		(21.5	)
Restructuring charges		2,201		—		100.0

Income from vessel operations		12,826		15,856		(19.1	)


Calendar-Ship-Days
Owned Vessels		2,430		2,373		2.4
Chartered-in Vessels		909		952		(4.5	)

Total		3,339		3,325		0.4


(1)		Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to the shuttle tanker segment based on estimated use of corporate resources).

Page 18 of 27

The average size of our owned shuttle tanker fleet increased for 2009 compared to 2008, primarily due to the purchase of a previously in-chartered shuttle tanker, which was delivered to us in late March 2008 (or the 2008 Shuttle Tanker Acquisition ).

Net Voyage Revenues. Net voyage revenues increased for the three months ended March 31, 2009, from the same period last year. This increase was primarily due to:

•

an increase of $4.0 million due to a decrease in number of offhire days resulting from scheduled drydockings and unexpected repairs during the three months ended March 31, 2009 compared to the same period last year;

•

an increase of $3.3 million due to a new time-charter agreement which began in December 2008; and

•

an increase of $1.8 million due to a decline in bunker prices during the three months ended March 31, 2009 compared to the same period last year;

partially offset by

•

a decrease of $4.1 million in revenues due to less revenue days for shuttle tankers servicing contracts of affreightment and trading in the conventional spot market compared to the same period last year.

Vessel Operating Expenses. Vessel operating expenses increased for the three months ended March 31, 2009, from the same period last year, primarily due to:

•

a net increase of $3.5 million from realized and unrealized losses on our designated foreign currency forward contracts;

•

an increase of $2.8 million due to an increase in services due to the rising cost of consumables, lube oil, and freight;

•

an increase of $2.2 million due to the 2008 Shuttle Tanker Acquisition and an additional bareboat chartered-in vessel beginning in December 2008; and

•

an increase of $2.3 million in salaries for crew and officers primarily due to general wage escalations;

partially offset by

•

a decrease of $0.7 million relating to repairs and maintenance performed for certain vessels during the three months ended March 31, 2009 compared to the same period last year.

Time-Charter Hire Expense. Time-charter hire expense decreased for the three months ended March 31, 2009, from the same period last year, primarily due to a net decrease of the in-chartered fleet.

Depreciation and Amortization. Depreciation and amortization expense increased for the three months ended March 31, 2009 from the same period last year, primarily due to the 2008 Shuttle Tanker Acquisition.

Conventional Tanker Segment

OPCO owns 11 Aframax conventional crude oil tankers, nine of which operate under fixed-rate time charters with Teekay Corporation. The remaining two vessels, which have additional equipment for lightering, operate under fixed-rate bareboat charters with Skaugen PetroTrans, Teekay Corporation’s 50%-owned joint venture.

The following table presents our conventional tanker segment’s operating results for the three months ended March 31, 2009 and 2008, and compares its net voyage revenues (which is a non-GAAP financial measure) for the three months ended March 31, 2009 and 2008 to voyage revenues, the most directly comparable GAAP financial measure, for the same periods. The following table also provides a summary of the changes in calendar-ship-days by owned vessels for our conventional tanker segment:


	Three Months Ended March 31,
(in thousands of U.S. dollars, except calendar-ship-days and percentages)	2009		2008		% Change
Voyage revenues		30,201		34,827		(13.3	)
Voyage expenses		6,339		12,476		(49.2	)

Net voyage revenues		23,862		22,351		6.8
Vessel operating expenses		5,390		5,959		(9.5	)
Depreciation and amortization		5,974		5,257		13.6
General and administrative ⁽¹⁾		1,434		2,204		(34.9	)

Income from vessel operations		11,064		8,931		23.9


Calendar-Ship-Days Owned Vessels		990		906		9.3


(1)		Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to the conventional tanker segment based on estimated use of corporate resources).

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The average size of the conventional crude oil tanker fleet increased for the three months ended March 31, 2009 compared to the same period last year, primarily due the acquisition of the Aframax tankers, the SPT Explorer and SPT Navigator, which began operations on January 7, 2008 and March 28, 2008, respectively (collectively, the 2008 Conventional Tanker Acquisitions ), and which we acquired in June 2008. (However, as a result of the inclusion of the Dropdown Predecessor, the SPT Explorer and the SPT Navigator have been included for accounting purposes in our results as if they were acquired on January 7, 2008 and March 28, 2008, respectively, when they completed construction and began operations as conventional tankers for Teekay Corporation. Please read “Items You Should Consider When Evaluating Our Results of Operations— Our financial results reflect the results of the interests in vessels acquired from Teekay Corporation for all periods the vessels were under common control” above).

Net Voyage Revenues. Net voyage revenues increased for the three months ended March 31, 2009, from the same period last year. This increase was primarily due to:

•

an increase of $1.3 million due to the 2008 Conventional Tanker Acquisitions; and

•

an increase of $1.2 million due to an increase in the daily hire rates for all nine time-charter contracts with Teekay Corporation and a decrease in offhire days during the three months ended March 31, 2009 compared to the same period last year;

partially offset by

•

a decrease of $1.0 million in net bunker revenues due to a general decrease in bunker index prices during the three months ended March 31, 2009 compared to the same period last year.

FSO Segment

Our FSO fleet consists of five vessels that operate under fixed-rate time charters or fixed-rate bareboat charters. Of the five FSO units, four are owned by OPCO and one is owned by us. FSO units provide an on-site storage solution to oil field installations that have no oil storage facilities or that require supplemental storage. Our voyage revenues and vessel operating expenses are affected by fluctuations in currency exchange rates, as a significant component of voyage revenues are earned and vessel operating expenses are incurred in Norwegian Kroner and Australian Dollars for certain vessels. The strengthening of the U.S. Dollar relative to the Norwegian Kroner and Australian Dollar may result in a significant decrease in our voyage revenues and a decrease in vessel operating expenses.

The following table presents our FSO segment’s operating results for the three months ended March 31, 2009 and 2008, and compares its net voyage revenues (which is a non-GAAP financial measure) for the three months ended March 31, 2009 and 2008 to voyage revenues, the most directly comparable GAAP financial measure, for the same periods. The following table also provides a summary of the changes in calendar-ship-days by owned vessels for our FSO segment:


	Three Months Ended March 31,
(in thousands of U.S. dollars, except calendar-ship-days and percentages)	2009		2008		% Change
Voyage revenues		15,089		17,046		(11.5	)
Voyage expenses		236		348		(32.2	)

Net voyage revenues		14,853		16,698		(11.0	)
Vessel operating expenses		5,822		6,312		(7.8	)
Depreciation and amortization		5,402		5,104		5.8
General and administrative ⁽¹⁾		440		829		(46.9	)

Income from vessel operations		3,189		4,453		(28.4	)


Calendar-Ship-Days Owned Vessels		450		455		(1.1	)


(1)		Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to the FSO segment based on estimated use of corporate resources).

Net Voyage Revenues. Net voyage revenues decreased for the three months ended March 31, 2009, from the same period last year. This decrease was primarily due to:

•

an decrease of $2.7 million due to primarily due to the strengthening of the U.S. Dollar against the Norwegian Kroner and Australian Dollar compared to the same period last year;

partially offset by

•

an increase of $0.7 million due to increases in our daily charter rates on certain vessels.

Vessel Operating Expenses. Vessel operating expenses decreased for the three months ended March 31, 2009, from the same period last year, primarily due to primarily due to the strengthening of the U.S. Dollar against the Norwegian Kroner and Australian Dollar compared to the same period last year.

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Other Operating Results

General and Administrative Expenses. General and administrative expenses decreased by $3.9 million for the three months ended March 31, 2009, from $15.8 million for the same period last year, primarily due to:

•

a decrease of $3.2 million in management fees payable to a subsidiary of Teekay Corporation for services rendered to us during the three months ended March 31, 2009. The decrease is primarily due to a reduction in the Teekay Corporation’s general and administrative costs, which are allocated to us through the management fee, including a decrease in accrued costs relating to a long-term incentive plan maintained by Teekay Corporation; and

•

a net decrease of $0.5 million from realized and unrealized gains and losses on our designated foreign currency forward contracts.

Restructuring Charges. Restructuring charges were $2.2 million for the three months ended March 31, 2009, resulting from the commencement of the reflagging of seven of our vessels from Norwegian flag to Bahamian flag and a change in the nationality mix of our crews. Under this plan, we expect to record and pay restructuring charges of approximately $4.4 million in total during 2009. We expect the restructuring will result in a reduction in future crewing costs for these vessels.

Interest Expense. Interest expense, which excludes realized and unrealized gains and losses from interest rate swaps, decreased to $10.6 million for the three months ended March 31, 2009, from $21.3 million for the same period last year, primarily due to:

•

a decrease of $4.7 million related to scheduled repayments of debt during 2008 and 2009; and

•

a decrease of $8.9 million due to a decline in interest rates during the three months ended March 31, 2009 compared to the same period last year;

partially offset by

•

an increase of $2.1 million due to the assumption of debt relating to the 2008 Shuttle Tanker Acquisition and the 2008 Conventional Tanker Acquisitions.

Realized and unrealized gains (losses) on non-designated derivatives . Net realized and unrealized gains on non-designated derivatives were $17.6 million for the three months ended March 31, 2009, compared to net realized and unrealized losses on non-designated derivatives of $45.4 million for the same period last year, as detailed in the table below:


	Three Months Ended, 31 March
(in thousands of U.S. Dollars)	2009			2008
Realized losses
Interest rate swaps		(8,460	)		(540	)
Foreign currency forward contracts		(2,934	)		—

		(11,394	)		(540	)


Unrealized gains (losses)
Interest rate swaps		26,626			(45,383	)
Foreign currency forward contracts		2,351			508

		28,977			(44,875	)


Total realized and unrealized gains (losses) on non-designated derivative instruments		17,583			(45,415	)

Foreign Currency Exchange Losses. Foreign currency exchange loss was $2.2 million for the three months ended March 31, 2009, compared to $2.5 million for the same period last year. Our foreign currency exchange losses and gains, substantially all of which are unrealized, are due primarily to the relevant period-end revaluation of Norwegian Kroner-denominated monetary assets and liabilities for financial reporting purposes. Gains reflect a stronger U.S. Dollar against the Norwegian Kroner on the date of revaluation or settlement compared to the rate in effect at the beginning of the period. Losses reflect a weaker U.S. Dollar against the Norwegian Kroner on the date of revaluation or settlement compared to the rate in effect at the beginning of the period.

Income Tax (Expense) Recovery. Income tax expense was $4.1 million for the three months ended March 31, 2009, compared to $0.9 million for the same period last year. The $3.2 million increase to income tax expense was primarily due to an increase in deferred income tax expense relating to investment and operational income for tax purposes for the three months ended March 31, 2009.

Other Income. Other income for the three months ended March 31, 2009 and 2008 was $3.1 million and $3.3 million, respectively, which was primarily comprised of leasing income from our volatile organic compound emissions equipment.

Net (Loss) Income. As a result of the foregoing factors, net income increased to $31.6 million for the three months ended March 31, 2009, from a loss of $36.2 million for the same period last year.

Page 21 of 27

Liquidity and Capital Resources

Liquidity and Cash Needs

As at March 31, 2009, our total cash and cash equivalents were $147.8 million, compared to $131.5 million at December 31, 2008. Our total liquidity, including cash, cash equivalents and undrawn long-term borrowings, was $295.5 million as at March 31, 2009, compared to $274.2 million as at December 31, 2008. The increase in liquidity was primarily the result of cash generated by our operating activities and a decrease in non-cash working capital during the three months ended March 31, 2009.

In addition to distributions on our equity interests, our primary short-term liquidity needs are to fund general working capital requirements and drydocking expenditures, while our long-term liquidity needs primarily relate to expansion and investment capital expenditures and other maintenance capital expenditures and debt repayment. Expansion capital expenditures are primarily for the purchase or construction of vessels to the extent the expenditures increase the operating capacity of or revenue generated by our fleet, while maintenance capital expenditures primarily consist of drydocking expenditures and expenditures to replace vessels in order to maintain the operating capacity of or revenue generated by our fleet. Investment capital expenditures are those capital expenditures that are neither maintenance capital expenditures nor expansion capital expenditures.

We believe that our existing cash and cash equivalents and undrawn long-term borrowings, in addition to all other sources of cash including cash from operations, will be sufficient to meet our existing liquidity needs for at least the next 12 months. Generally, our long-term sources of funds will be from cash from operations, long-term bank borrowings and other debt or equity financings, or a combination thereof. Because we and OPCO distribute all of our and its available cash, we expect that we and OPCO will rely upon external financing sources, including bank borrowings and the issuance of debt and equity securities, to fund acquisitions and expansion and investment capital expenditures, including opportunities we may pursue under the omnibus agreement with Teekay Corporation and other of its affiliates.

Cash Flows. The following table summarizes our sources and uses of cash for the periods presented:


	Three Months Ended March 31,
(in thousands of U.S. dollars)	2009			2008
Net cash flow from operating activities		53,882			48,011
Net cash flow from financing activities		(40,576	)		8,657
Net cash flow from investing activities		3,043			(40,101	)

Operating Cash Flows. Net cash flow from operating activities increased to $53.9 million for the three months ended March 31, 2009, from $48.0 million for the same period in 2008, primarily due to a net increase in changes to non-cash working capital items, an increase in net voyage revenues, and a decrease in expenditures for drydocking, partially offset by an increase in vessel operating expenses due to a trend of increasing crew compensation and increases in repairs and maintenance costs. Net cash flow from operating activities depends upon the timing and amount of drydocking expenditures, repairs and maintenance activity, vessel additions and dispositions, foreign currency rates, changes in interest rates, fluctuations in working capital balances, shuttle tanker utilization and spot market hire rates. The number of vessel drydockings tends to be uneven between years.

Financing Cash Flows. Scheduled debt repayments were $7.2 million and $8.0 million during the three months ended March 31, 2009 and 2008, respectively. Prepayment of long-term debt totaled $5.0 million and $17.0 million during the three months ended March 31, 2009 and March 31, 2008, respectively.

Cash distributions paid by OPCO to non-controlling interest owners were $13.9 million and $24.0 million during the three months ended March 31, 2009 and 2008, respectively.

Cash distributions paid during the three months ended March 31, 2009 and 2008 totaled $14.4 million and $8.0 million, respectively. Subsequent to March 31, 2009, cash distributions for the three months ended March 31, 2009 were declared and paid during the second quarter of 2009 and totaled $14.2 million.

Investing Cash Flows. During the three months ended March 31, 2009, we incurred $2.5 million of expenditures for vessels and equipment, primarily relating to vessel conversion costs. During the three months ended March 31, 2009 and 2008, we received $5.5 million and $5.9 million, respectively, in scheduled repayments received from the leasing of our volatile organic compound emissions equipment.

Credit Facilities

As at March 31, 2009, our total debt was $1,554.3 million, compared to $1,566.4 million as at December 31, 2008. As at March 31, 2009, we had seven revolving credit facilities available, which, as at such date, provided for borrowings of up to $1,453 million, of which $147.7 million was undrawn. As at March 31, 2009, five of our six 50%-owned subsidiaries had an outstanding term loan, which, in aggregate, totaled $248.7 million. The term loans for these 50%-owned subsidiaries reduce in semi-annual payments with varying maturities through 2017. Please read Item 1 — Financial Statements: Note 5 — Long-Term Debt.

Our seven revolving credit facilities are described in Note 5 — Long-Term Debt, to our consolidated financial statements included in this report.

Page 22 of 27

Five of the revolving credit facilities contain covenants that require OPCO to maintain the greater of a minimum liquidity (cash, cash equivalents and undrawn committed revolving credit lines with at least six months of maturity) of at least $75.0 million and 5.0% of OPCO’s total consolidated debt. The remaining revolving credit facility is guaranteed by Teekay Corporation and contains covenants that require Teekay Corporation to maintain the greater of a minimum liquidity of $50.0 million and 5.0% of Teekay Corporation’s total debt which has recourse to Teekay Corporation. As at March 31, 2009, we, OPCO and Teekay Corporation were in compliance with all of our covenants under these credit facilities.

The term loans of our 50%-owned subsidiaries are collateralized by first-priority mortgages on the vessels to which the loans relate, together with other related collateral. As at March 31, 2009, we had guaranteed $74.2 million of these term loans, which represents our 50% share of the outstanding vessel mortgage debt in four of these 50%-owned subsidiaries. The other owner and Teekay Corporation have guaranteed the remaining $174.5 million.

Interest payments on the revolving credit facilities and term loans are based on LIBOR plus a margin. At March 31, 2009 and December 31, 2008, the margins ranged between 0.45% and 0.95%.

All of our vessel financings are collateralized by the applicable vessels. The term loans used to finance the five 50%-owned subsidiaries and our revolving credit facility agreements contain typical covenants and other restrictions, including those that restrict the relevant subsidiaries from:

•

incurring or guaranteeing indebtedness (applicable to our term loans and two of our revolving credit facilities);

•

changing ownership or structure, including by mergers, consolidations, liquidations and dissolutions;

	•		making dividends or distributions when in default of the relevant loans;

	•		making capital expenditures in excess of specified levels;

	•		making certain negative pledges or granting certain liens;

	•		selling, transferring, assigning or conveying assets; or

	•		entering into a new line of business.

We conduct our funding and treasury activities within corporate policies designed to minimize borrowing costs and maximize investment returns while maintaining the safety of the funds and appropriate levels of liquidity for our purposes. We hold cash and cash equivalents primarily in U.S. Dollars.

Contractual Obligations and Contingencies

The following table summarizes our long-term contractual obligations as at March 31, 2009:


			Balance		2010		2012
			of		and		and		Beyond
	Total		2009		2011		2013		2013
	(in millions of U.S. dollars)
Long-term debt ⁽¹⁾		1,554.3		113.3		304.0		302.6		834.4
Chartered-in vessels (operating leases)		363.4		79.4		151.4		103.6		29.0

Total contractual obligations		1,917.7		192.7		455.4		406.2		863.4


(1)		Excludes expected interest payments of $25.6 million (remainder of 2009), $60.1 million (2010 and 2011), $46.1 million (2012 and 2013) and $22.7 million (beyond 2013). Expected interest payments are based on LIBOR, plus margins which ranged between 0.45% and 0.95% as at March 31, 2009.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements that have or are reasonably likely to have, a current or future material effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

CRITICAL ACCOUNTING ESTIMATES

We prepare our consolidated financial statements in accordance with GAAP, which require us to make estimates in the application of our accounting policies based on our best assumptions, judgments and opinions. On a regular basis, management reviews the accounting policies, assumptions, estimates and judgments to ensure that our consolidated financial statements are presented fairly and in accordance with GAAP. However, because future events and their effects cannot be determined with certainty, actual results could differ from our assumptions and estimates, and such differences could be material. Accounting estimates and assumptions that we consider to be the most critical to an understanding of our financial statements because they inherently involve significant judgments and uncertainties, can be found in Item 5. Operating and Financial Review and Prospects, in our Annual Report on Form 20-F for the year ended December 31, 2008.

Page 23 of 27

FORWARD-LOOKING STATEMENTS

This Report on Form 6-K for the three months ended March 31, 2009 contains certain forward-looking statements (as such term is defined in Section 27A of the Securities Exchange Act of 1933 as amended, and Section 21E of the Securities Exchange Act of 1934, as amended) concerning future events and our operations, performance and financial condition, including, in particular, statements regarding:

•

our future growth prospects;

•

results of operations and revenues and expenses;

•

offshore and tanker market fundamentals, including the balance of supply and demand in the offshore and tanker market;

•

future capital expenditures and availability of capital resources to fund capital expenditures;

•

offers of shuttle tankers, FSOs and FPSOs and related contracts from Teekay Corporation;

•

obtaining offshore projects that we or Teekay Corporation bid on or have been awarded;

•

delivery dates of and financing for newbuildings or existing vessels;

•

entrance into joint ventures and partnerships with companies;

•

the commencement of service of newbuildings or existing vessels;

•

our liquidity needs;

•

our exposure to foreign currency fluctuations, particularly in Norwegian Kroner; and

•

the outcome of claims and legal action arising from the collision involving the Navion Hispania .

Forward-looking statements include, without limitation, any statement that may predict, forecast, indicate or imply future results, performance or achievements, and may contain the words “believe”, “anticipate”, “expect”, “estimate”, “project”, “will be”, “will continue”, “will likely result”, “plan”, “intend” or words or phrases of similar meanings. These statements involve known and unknown risks and are based upon a number of assumptions and estimates that are inherently subject to significant uncertainties and contingencies, many of which are beyond our control. Actual results may differ materially from those expressed or implied by such forward-looking statements. Important factors that could cause actual results to differ materially include, but are not limited to: changes in production of oil from offshore oil fields; changes in the demand for offshore oil transportation, production and storage services; greater or less than anticipated levels of vessel newbuilding orders or greater or less than anticipated rates of vessel scrapping; changes in trading patterns; changes in the Partnership’s expenses; changes in applicable industry laws and regulations and the timing of implementation of new laws and regulations; potential inability to implement our growth strategy; competitive factors in the markets in which we operate; potential for early termination of long-term contracts and our potential inability to renew or replace long-term contracts; loss of any customer, time charter or vessel; shipyard production or vessel delivery delays; our potential inability to raise financing to purchase additional vessels; our exposure to currency exchange rate fluctuations; changes to the amount of proportion of revenues and expenses denominated in foreign currencies; and other factors detailed from time to time in our periodic reports filed with the SEC, including our Annual Report on Form 20-F for the year ended December 31, 2008. We do not intend to release publicly any updates or revisions to any forward-looking statements contained herein to reflect any change in our expectations with respect thereto or any change in events, conditions or circumstances on which any such statement is based.

Page 24 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES
MARCH 31, 2009
PART I — FINANCIAL INFORMATION

ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

We are exposed to the impact of interest rate changes primarily through our borrowings that require us to make interest payments based on LIBOR. Significant increases in interest rates could adversely affect operating margins, results of operations and our ability to service debt. We use interest rate swaps to reduce exposure to market risk from changes in interest rates. The principal objective of these contracts is to minimize the risks and costs associated with the floating-rate debt.

In order to minimize counterparty risk, we only enter into derivative transactions with counterparties that are rated A or better by Standard & Poor’s or Aa3 by Moody’s at the time of the transactions. In addition, to the extent possible and practical, interest rate swaps are entered into with different counterparties to reduce concentration risk.

The tables below provide information about financial instruments as at March 31, 2009 that are sensitive to changes in interest rates. For long-term debt, the table presents principal payments and related weighted-average interest rates by expected maturity dates. For interest rate swaps, the table presents notional amounts and weighted-average interest rates by expected contractual maturity dates.


	Expected Maturity Date
	Balance
	of																					Fair Value
	2009			2010			2011			2012			2013			Thereafter			Total			Liability			Rate ⁽¹⁾
	(in millions of U.S. dollars, except percentages)
Long-Term Debt:
Variable Rate ⁽²⁾		113.3			134.7			169.3			147.1			155.5			834.4			1,554.3			(1,469.0	)		2.3	%

Interest Rate Swaps:
Contract Amount ⁽³⁾		351.6			18.1			18.7			19.2			19.9			703.8			1,131.3			(137.5	)		4.9	%
Average Fixed Pay Rate ⁽²⁾		4.9	%		4.9	%		4.9	%		4.9	%		4.9	%		4.8	%		4.9	%


(1)		Rate refers to the weighted-average effective interest rate for our debt, including the margin paid on our floating-rate debt and the average fixed pay rate for interest rate swaps. The average fixed pay rate for interest rate swaps excludes the margin paid on the floating-rate debt, which as of March 31, 2009 ranged from 0.45% to 0.95%.

(2)		Interest payments on floating-rate debt and interest rate swaps are based on LIBOR.

(3)		The average variable receive rate for interest rate swaps is set quarterly at the 3-month LIBOR or semi-annually at the 6-month LIBOR.

Foreign Currency Fluctuation Risk

Our functional currency is U.S. dollars because virtually all of our revenues and most of our operating costs are in U.S. Dollars. We incur certain vessel operating expenses and general and administrative expenses in foreign currencies, the most significant of which is the Norwegian Kroner and, to a lesser extent, Australian Dollars, British Pounds, Euros and Singapore Dollars. There is a risk that currency fluctuations will have a negative effect on the value of cash flows.

We may continue to seek to hedge these currency fluctuation risks in the future. At March 31, 2009, we were committed to the following foreign currency forward contracts:


	Contract Amount in		Average		Expected Maturity
	Foreign Currency		Forward Rate ⁽¹⁾		2009		2010
	(thousands)				(in thousands of U.S. Dollars)
Norwegian Kroner		1,044,561		5.89	$	81,426	$	96,068
Australian Dollar		2,819		1.12		2,516		—
British Pound		273		0.52		422		99
Euro		18,750		0.70		14,624		12,254

					$	98,988	$	108,421


(1)		Average forward rate represents the contracted amount of foreign currency one U.S. Dollar will buy.

Although the majority of transactions, assets and liabilities are denominated in U.S. Dollars, OPCO had Norwegian Kroner-denominated deferred income taxes of approximately 90.9 million ($13.9 million) at March 31, 2009. Neither we nor OPCO has entered into any forward contracts to protect against currency fluctuations on any future taxes.

Page 25 of 27

TEEKAY OFFSHORE PARTNERS L.P. AND SUBSIDIARIES
MARCH 31, 2009

PART II — OTHER INFORMATION

Item 1 — Legal Proceedings

On November 13, 2006, a Teekay Offshore Operating L.P. (or OPCO ) shuttle tanker, the Navion Hispania , collided with the Njord Bravo , a floating storage and offtake unit, while preparing to load an oil cargo from the Njord Bravo . The Njord Bravo services the Njord field, which is operated by StatoilHydro Petroleum AS (or StatoilHydro ) and is located off the Norwegian coast. At the time of the incident, StatoilHydro was chartering the Navion Hispania from OPCO. The Navion Hispania and the Njord Bravo both incurred damages as a result of the collision.

In November 2007, Navion Offshore Loading AS, a subsidiary of OPCO, and two subsidiaries of Teekay Corporation were named as co-defendants in a legal action filed by Norwegian Hull Club (the hull and machinery insurers of the Njord Bravo ), StatoilHydro and various licensees in the Njord field. The claim seeks damages for vessel repairs, expenses for a replacement vessel and other amounts related to production stoppage on the field, totaling NOK256,000,000 (or approximately USD$41 million). As anticipated, the Stavanger Conciliation Council has referred the matter to the Stavanger District Court. The claimants must continue the proceedings by December 31, 2009 in order to avoid the matter being time-barred.

The Partnership believes the likelihood of any losses relating to the claim is remote. OPCO believes that the charter contract relating to the Navion Hispania requires that StatoilHydro be responsible and indemnify Navion Offshore Loading AS for all losses relating to the damage to the Njord Bravo . OPCO and Teekay Corporation also maintain insurance for damages to the Navion Hispania and insurance for collision-related costs and claims. The Partnership believes that these insurance policies will cover the costs related to this incident, including any costs not indemnified by StatoilHydro, subject to standard deductibles. In addition, Teekay Corporation has agreed to indemnify the Partnership, OPCO and OPCO’s subsidiaries for any losses they may incur in connection with this incident.

Item 1A — Risk Factors

In addition to the other information set forth in this Report on Form 6-K/A, you should carefully consider the risk factors discussed in Part I, “Item 3. Key Information — Risk Factors” in our Annual Report on Form 20-F for the year ended December 31, 2008, which could materially affect our business, financial condition or results of operations. There have been no material changes in our risk factors from those disclosed in our 2008 Annual Report on Form 20-F.

Item 2 — Unregistered Sales of Equity Securities and Use of Proceeds

None

Item 3 — Defaults Upon Senior Securities

None

Item 4 — Submission of Matters to a Vote of Security Holders

None

Item 5 — Other Information

None

Item 6 — Exhibits

None

THIS REPORT ON FORM 6-K IS HEREBY INCORPORATED BY REFERENCE INTO THE FOLLOWING REGISTRATION STATEMENT OF THE PARTNERSHIP:

•		REGISTRATION STATEMENT ON FORM S-8 (NO. 333-147682) FILED WITH THE SEC ON NOVEMBER 28, 2007

•		REGISTRATION STATEMENT ON FORM F-3 (NO. 333-150682) FILED WITH THE SEC ON MAY 6, 2008

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SIGNATURES

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


	TEEKAY OFFSHORE PARTNERS L.P.
	By:	Teekay Offshore GP L.L.C., its general partner

Date: July 29, 2009	By:	/s/ Peter Evensen
		Peter Evensen
		Chief Executive Officer and Chief Financial Officer (Principal Financial and Accounting Officer)

Page 27 of 27

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