Seapeak (SEAL-PA) 20-F 26 Apr 17 2016 FY Annual report (foreign) Financial data

Document and Entity Information

Document and Entity Information	12 Months Ended
	Dec. 31, 2016shares
Document And Entity Information [Abstract]
Document Type	20-F
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Trading Symbol	TGP
Entity Registrant Name	Teekay LNG Partners L.P.
Entity Central Index Key	1,308,106
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	79,571,820

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Voyage revenues (note 11)	$ 396,444	$ 397,991	$ 402,928
Voyage expenses	(1,656)	(1,146)	(3,321)
Vessel operating expenses (note 11)	(88,590)	(94,101)	(95,808)
Depreciation and amortization	(95,542)	(92,253)	(94,127)
General and administrative expenses (notes 11 and 16)	(18,499)	(25,118)	(23,860)
Restructuring charges (note 17)	0	(4,001)	(1,989)
Write-down and loss on sale of vessels (note 18)	(38,976)	0	0
Income (loss) from vessel operations	153,181	181,372	183,823
Equity income (notes 6 and 13d)	62,307	84,171	115,478
Interest expense	(58,844)	(43,259)	(60,414)
Interest income	2,583	2,501	3,052
Realized and unrealized loss on non-designated derivative instruments (note 12)	(7,161)	(20,022)	(44,682)
Foreign currency exchange gain (notes 9 and 12)	5,335	13,943	28,401
Other income	1,537	1,526	836
Net income before income tax expense	158,938	220,232	226,494
Income tax expense (note 10)	(973)	(2,722)	(7,567)
Net income	157,965	217,510	218,927
Non-controlling interest in net income	17,514	16,627	13,489
Preferred unitholders' interest in net income	2,719	0	0
General Partner's interest in net income	2,755	26,276	31,187
Limited partners’ interest in net income	$ 134,977	$ 174,607	$ 174,251
Limited partners’ interest in net income per common unit (note 15):
Basic (in dollars per share)	$ 1.70	$ 2.21	$ 2.30
Diluted (in dollars per share)	$ 1.69	$ 2.21	$ 2.30
Weighted-average number of common units outstanding (note 15):
Basic (in shares)	79,568,352	78,896,767	75,664,435
Diluted (in shares)	79,671,858	78,961,102	75,702,886
Cash distributions declared per common unit (in dollars per share)	$ 0.56	$ 2.80	$ 2.77

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ 157,965	$ 217,510	$ 218,927
Other comprehensive income (loss) :
Unrealized loss on qualifying cash flow hedging instruments, net of tax (note 12)	(486)	(1,723)	(3,085)
Amounts reclassified from accumulated other comprehensive income (loss) to equity income:
Realized loss on qualifying cash flow hedging instruments	3,289	1,075	1,551
Other comprehensive income (loss)	2,803	(648)	(1,534)
Comprehensive income	160,768	216,862	217,393
Non-controlling interest in comprehensive income	17,691	16,627	13,489
Preferred unitholders' interest in net income	2,719	0	0
General and limited partners' interest in comprehensive income	$ 140,358	$ 200,235	$ 203,904

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Current
Cash and cash equivalents	$ 126,146	$ 102,481
Restricted cash - current (note 5)	10,145	6,600
Accounts receivable, including non-trade of $19,325 (2015 – $7,058) (note 6a iii)	25,224	22,081
Prepaid expenses	3,724	4,469
Vessel held for sale (note 18)	20,580	0
Current portion of derivative assets (note 12)	531	0
Current portion of net investments in direct financing leases (note 5)	150,342	20,606
Advances to affiliates (notes 11g and 12)	9,739	13,026
Total current assets	346,431	169,263
Restricted cash – long-term (note 5)	106,882	104,919
Vessels and equipment
At cost, less accumulated depreciation of $668,969 (2015 – $666,710)	1,374,128	1,595,077
Vessels under capital leases, at cost, less accumulated depreciation of $69,072 (2015 – $56,316) (note 5)	484,253	88,215
Advances on newbuilding contracts (notes 11f and 13a)	357,602	424,868
Total vessels and equipment	2,215,983	2,108,160
Investment in and advances to equity accounted joint ventures (note 6)	1,037,726	883,731
Net investments in direct financing leases (note 5)	492,666	646,052
Other assets (note 6a iii)	5,529	20,811
Derivative assets (note 12)	4,692	5,623
Intangible assets – net (note 7)	69,934	78,790
Goodwill – liquefied gas segment (note 7)	35,631	35,631
Total assets	4,315,474	4,052,980
Current
Accounts payable	5,562	2,770
Accrued liabilities (notes 8, 12 and 17)	35,881	37,456
Unearned revenue (note 5)	16,998	19,608
Current portion of long-term debt (note 9)	188,511	197,197
Current obligations under capital lease (note 5)	40,353	4,546
Current portion of in-process contracts (note 6a iii)	15,833	12,173
Current portion of derivative liabilities (note 12)	56,800	52,083
Advances from affiliates (notes 11g and 12)	15,492	22,987
Total current liabilities	375,430	348,820
Long-term debt (note 9)	1,602,715	1,802,012
Long-term obligations under capital lease (note 5)	352,486	54,581
Long-term unearned revenue	10,332	30,333
Other long-term liabilities (notes 5, 6a and 6b)	60,573	71,152
In-process contracts (note 6a iii)	8,233	20,065
Derivative liabilities (note 12)	128,293	182,338
Total liabilities	2,538,062	2,509,301
Commitments and contingencies (notes 5, 6, 9, 12, and 13)
Equity
General Partner	50,653	48,786
Accumulated other comprehensive income (loss)	575	(2,051)
Partners' equity	1,738,506	1,519,062
Non-controlling interest	38,906	24,617
Total equity	1,777,412	1,543,679
Total liabilities and total equity	4,315,474	4,052,980
Common Units
Equity
Limited Partners - common units (79.6 million units issued and outstanding at December 31, 2016 and 2015) (note 15)	1,563,852	1,472,327
Preferred Units
Equity
Limited Partners - preferred units (5.0 million and nil units issued and outstanding at December 31, 2016 and 2015, respectively) (note 15)	$ 123,426	$ 0

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Non-trade accounts receivable	$ 19,325	$ 7,058
Accumulated depreciation on vessel and equipment	668,969	666,710
Accumulated depreciation on vessels under capital leases	$ 69,072	$ 56,316
Common Units
Units issued (in shares)	79,600,000	79,600,000
Units outstanding (in shares)	79,600,000	79,600,000
Preferred Units
Units issued (in shares)	5,000,000	0
Units outstanding (in shares)	5,000,000	0

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
OPERATING ACTIVITIES
Net income	$ 157,965	$ 217,510	$ 218,927
Non-cash items:
Unrealized (gain) loss on derivative instruments (note 12)	(19,433)	(12,375)	2,096
Depreciation and amortization	95,542	92,253	94,127
Write-down and loss on sale of vessels	38,976	0	0
Unrealized foreign currency exchange gain and other (notes 9 and 12)	(42,009)	(26,090)	(24,931)
Equity income, net of dividends received of $31,113 (2015 – $97,146 and 2014 – $11,005)	(31,194)	12,975	(104,473)
Change in operating assets and liabilities (note 14a)	(20,669)	(34,187)	18,822
Expenditures for dry docking	(12,686)	(10,357)	(13,471)
Net operating cash flow	166,492	239,729	191,097
FINANCING ACTIVITIES
Proceeds from issuance of long-term debt	573,514	391,574	944,123
Scheduled repayments of long-term debt	(316,450)	(126,557)	(100,804)
Prepayments of long-term debt	(463,422)	(90,000)	(608,501)
Debt issuance costs	(3,462)	(2,856)	(6,431)
Scheduled repayments and prepayments of capital lease obligations	(21,594)	(4,423)	(479,115)
Proceeds from equity offerings, net of offering costs (note 15)	120,707	35,374	182,139
Decrease (increase) in restricted cash	4,651	(30,321)	448,914
Cash distributions paid	(45,467)	(255,519)	(240,525)
Novation of derivative liabilities (note 11e)	0	0	2,985
Dividends paid to non-controlling interest	(3,402)	(1,629)	(42,716)
Net financing cash flow	(154,925)	(84,357)	100,069
INVESTING ACTIVITIES
Purchase of and additional capital contributions in equity accounted investments	(120,879)	(25,852)	(100,200)
Loan repayments from equity accounted joint ventures	5,500	23,744	631
Receipts from direct financing leases	23,650	15,837	17,200
Proceeds from sale of vessels (note 18a)	94,311	0	0
Proceeds from sale-lease back of vessels	355,306	0	0
Expenditures for vessels and equipment (note 14e)	(345,790)	(191,969)	(188,855)
Increase in restricted cash	0	(34,290)	0
Other	0	0	216
Net investing cash flow	12,098	(212,530)	(271,008)
Increase (decrease) in cash and cash equivalents	23,665	(57,158)	20,158
Cash and cash equivalents, beginning of the year	102,481	159,639	139,481
Cash and cash equivalents, end of the year	$ 126,146	$ 102,481	$ 159,639

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Cash Flows [Abstract]
Dividends received	$ 31,113	$ 97,146	$ 11,005

Consolidated Statement of Chang

Consolidated Statement of Changes in Total Equity - USD ($) $ in Thousands	Total	General Partner	Common UnitsLimited Partners	Preferred UnitsLimited Partners	Accumulated Other Comprehensive Income (Loss)	Non- controlling Interest
Beginning balance, units at Dec. 31, 2013			74,196,000
Beginning balance at Dec. 31, 2013	$ 1,443,784	$ 52,526	$ 1,338,133		$ 131	$ 52,994
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	218,927	31,187	174,251			13,489
Other comprehensive income (loss)	(1,534)				(1,534)
Cash distributions	(240,525)	(30,900)	$ (209,625)
Dividends paid to non-controlling interest	(57,080)					(57,080)
Equity based compensation, net of tax, units			17,000
Equity based compensation, net of tax	$ 1,444	29	$ 1,415
Proceeds from equity offerings, units	1,050,463		4,140,000
Proceeds from equity offerings	$ 182,139	3,666	$ 178,473
Sale of 1% interest in Norgas Napa to General Partner (note 11d)	216					216
Ending balance, units at Dec. 31, 2014			78,353,000
Ending balance at Dec. 31, 2014	1,547,371	56,508	$ 1,482,647		(1,403)	9,619
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	217,510	26,276	174,607			16,627
Other comprehensive income (loss)	(648)				(648)
Cash distributions	(255,519)	(34,747)	$ (220,772)
Dividends paid to non-controlling interest	(1,629)					(1,629)
Equity based compensation, net of tax, units			25,000
Equity based compensation, net of tax	$ 1,220	24	$ 1,196
Proceeds from equity offerings, units	1,173,428		1,173,000
Proceeds from equity offerings	$ 35,374	725	$ 34,649
Ending balance, units at Dec. 31, 2015			79,551,000	0
Ending balance at Dec. 31, 2015	1,543,679	48,786	$ 1,472,327	$ 0	(2,051)	24,617
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	157,965	2,755	134,977	$ 2,719		17,514
Other comprehensive income (loss)	2,803				2,626	177
Cash distributions	(45,467)	(910)	$ (44,557)
Dividends paid to non-controlling interest	(3,402)					(3,402)
Equity based compensation, net of tax, units			21,000
Equity based compensation, net of tax	1,127	22	$ 1,105
Proceeds from equity offerings, units				5,000,000
Proceeds from equity offerings	120,707			$ 120,707
Ending balance, units at Dec. 31, 2016			79,572,000	5,000,000
Ending balance at Dec. 31, 2016	$ 1,777,412	$ 50,653	$ 1,563,852	$ 123,426	$ 575	$ 38,906

Consolidated Statement of Chan9

Consolidated Statement of Changes in Total Equity (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Partners' Capital [Abstract]
Percentage interest on sale			1.00%
Equity based compensation, tax	$ 0.2	$ 0.4

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Basis of Presentation The 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 LNG Partners L.P. (or the Partnership ), which is a limited partnership organized under the laws of the Republic of The Marshall Islands and its wholly owned or controlled subsidiaries. The preparation of consolidated 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 may differ from those estimates. Significant intercompany balances and transactions have been eliminated upon consolidation. In addition, certain of the comparative figures have been reclassified to conform to the presentation adopted in the current period relating to certain operating activities in the Partnership's consolidated statements of cash flows and certain of the summarized financial information in Note 6c. Foreign currency The consolidated financial statements are stated in U.S. Dollars and the functional currency of the Partnership and its subsidiaries is the U.S. Dollar. Transactions involving other currencies during the year are converted into U.S. Dollars using the exchange rates in effect at the time of the transactions. At the balance sheet date, monetary assets and liabilities that are denominated in currencies other than the U.S. Dollar are translated to reflect the year-end exchange rates. Resulting gains or losses are reflected separately in the accompanying consolidated statements of income. Operating revenues and expenses The lease element of time-charters and bareboat charters accounted for as operating leases are recognized by the Partnership on a straight-line basis daily over the term of the charter as the applicable vessel operates under the charter. The lease element of the Partnership’s time-charters that are accounted for as direct financing leases are reflected on the balance sheets as net investments in direct financing leases. The lease element is recognized over the lease term using the effective interest rate method and is included in voyage revenues. The Partnership recognizes revenues from the non-lease element of time-charter contracts as services are performed. The Partnership does not recognize revenues during days that the vessel is off-hire. Voyage expenses are all expenses unique to a particular voyage, including bunker fuel expenses, port fees, cargo loading and unloading expenses, canal tolls, agency fees and commissions. Vessel operating expenses include crewing, ship management services, repairs and maintenance, insurance, stores, lube oils and communication expenses. Voyage expenses and vessel operating expenses are recognized when incurred. Cash and cash equivalents The Partnership classifies all highly-liquid investments with a maturity date of three months or less when purchased as cash and cash equivalents. Accounts receivable and allowance for doubtful accounts Accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts is the Partnership’s best estimate of the amount of probable credit losses in existing accounts receivable. The Partnership determines the allowance based on historical write-off experience and customer economic data. The Partnership reviews the allowance for doubtful accounts regularly and past due balances are reviewed for collectability. Account balances are charged against the allowance when the Partnership believes that the receivable will not be recovered. Vessels and equipment All pre-delivery costs incurred during the construction of newbuildings, including interest and supervision and technical costs, are capitalized. The acquisition cost and all costs incurred to restore used vessels purchased by the Partnership to the standards required to properly service the Partnership’s customers are capitalized. Depreciation is calculated on a straight-line basis over a vessel’s estimated useful life, less an estimated residual value. Depreciation is calculated using an estimated useful life of 25 years for conventional tankers, 30 years for liquefied petroleum gas (or LPG ) carriers and 35 years for liquefied natural gas (or LNG ) carriers, from the date the vessel is delivered from the shipyard, or a shorter period if regulations prevent the Partnership from operating the vessels for 25 years , 30 years , or 35 years , respectively. Depreciation of vessels and equipment for the years ended December 31, 2016 , 2015 and 2014 aggregated $86.6 million , $83.4 million and $70.1 million , respectively. Depreciation and amortization includes depreciation on all owned vessels and amortization of vessels accounted for as capital leases. Vessel capital modifications include the addition of new equipment or can encompass various modifications to the vessel which are aimed at improving or increasing the operational efficiency and functionality of the asset. This type of expenditure is amortized over the estimated useful life of the modification. Expenditures covering recurring routine repairs and maintenance are expensed as incurred. Interest costs capitalized to vessels and equipment for the years ended December 31, 2016 , 2015 and 2014 aggregated $9.9 million , $8.2 million and $3.1 million , respectively. Generally, the Partnership dry docks each of its vessels every five years. In addition, a shipping society classification intermediate survey is performed on the Partnership’s LNG and LPG carriers between the second and third year of the five -year dry-docking cycle. The Partnership capitalizes certain costs incurred during dry docking and for the survey and amortizes those costs on a straight-line basis from the completion of a dry docking or intermediate survey over the estimated useful life of the dry dock. The Partnership includes in capitalized dry docking those costs incurred as part of the dry docking to meet regulatory requirements, or expenditures that either add economic life to the vessel, increase the vessel’s earning capacity or improve the vessel’s operating efficiency. The Partnership expenses costs related to routine repairs and maintenance performed during dry docking that do not improve operating efficiency or extend the useful lives of the assets. The following table summarizes the change in the Partnership’s capitalized dry docking costs, from January 1, 2014 to December 31, 2016 : Year Ended December 31, 2016 2015 2014 Balance at January 1, 33,916 33,635 40,328 Cost incurred for dry docking 13,944 10,357 13,471 Sales of vessels (2,886 ) — (5,327 ) Dry-dock amortization (11,436 ) (10,076 ) (14,837 ) Balance at December 31, 33,538 33,916 33,635 Vessels and equipment that are “held and used” are assessed for impairment when events or circumstances indicate the carrying amount of the asset may not be recoverable. If the asset’s net carrying value exceeds the net undiscounted cash flows expected to be generated over its remaining useful life, the carrying amount of the asset is reduced to its estimated fair value. The estimated fair value for the Partnership’s impaired vessels is determined using discounted cash flows or appraised values. In cases where an active second hand sale and purchase market does not exist, the Partnership uses a discounted cash flow approach to estimate the fair value of an impaired vessel. In cases where an active second hand sale and purchase market exists, an appraised value is generally the amount the Partnership would expect to receive if it were to sell the vessel. Such appraisal is normally completed by the Partnership. Vessels and equipment that are held for sale are measured at the lower of their carrying amount or fair value less costs to sell and are not depreciated while classified as held for sale. Interest and other expenses attributable to vessels and equipment classified as held for sale, or to their related liabilities, continue to be recognized as incurred. Gains on vessels sold and leased back under capital leases are deferred and amortized over the remaining term of the capital lease. Losses on vessels sold and leased back under capital leases are recognized immediately when the fair value of the vessel at the time of sale and lease-back is less than its book value. In such case, the Partnership would recognize a loss in the amount by which book value exceeds fair value. Investments in and advances to equity accounted joint ventures The Partnership’s investments in certain joint ventures are accounted for using the equity method of accounting. Under the equity method of accounting, investments are stated at initial cost and are adjusted for subsequent additional investments and the Partnership’s proportionate share of earnings or losses and distributions. In addition, the Partnership’s advances to equity accounted joint ventures are recorded at cost. The Partnership evaluates its investment in and advances to equity accounted joint ventures for impairment when events or circumstances indicate that the carrying value of such investments may have experienced an other-than-temporary decline in value below its carrying value. If the estimated fair value is less than the carrying value, the carrying value is written down to its estimated fair value and the resulting impairment is recorded in the Partnership’s consolidated statements of income. Debt issuance costs Debt issuance costs, including fees, commissions and legal expenses, are presented as a direct reduction from the carrying amount of the debt liability with the exception if debt issuance costs are not attributable to a specific debt liability or the debt issuance costs exceed the carrying value of the related debt liability, the debt issuance costs are deferred and presented as other assets in the Partnership's consolidated balance sheets. Debt issuance costs are amortized on an effective interest rate method over the term of the relevant loan. Amortization of debt issuance costs is included in interest expense. Goodwill and intangible assets Goodwill is not amortized, but reviewed for impairment at the reporting unit level on an annual basis or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. When goodwill is reviewed for impairment, the Partnership may elect to assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, including goodwill. Alternatively, the Partnership may bypass this step and use a fair value approach to identify potential goodwill impairment and, when necessary, measure the amount of impairment. The Partnership uses a discounted cash flow model to determine the fair value of reporting units, unless there is a readily determinable fair market value. Intangible assets are assessed for impairment when and if impairment indicators exist. An impairment loss is recognized if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. The Partnership’s finite life intangible assets consist of acquired time-charter contracts and are amortized on a straight-line basis over the remaining term of the time-charters. Finite life intangible assets are assessed for impairment when events or circumstances indicate that the carrying value may not be recoverable. Derivative instruments All derivative instruments are initially recorded at fair value as either assets or liabilities in the accompanying consolidated balance sheet and subsequently remeasured to fair value, regardless of the purpose or intent for holding the derivative. The method of recognizing the resulting gain or loss is dependent on whether the derivative contract is designed to hedge a specific risk and whether the contract qualifies for hedge accounting. When a derivative is designated as a cash flow hedge, the Partnership formally documents the relationship between the derivative and the hedged item. This documentation includes the strategy and risk management objective for undertaking the hedge and the method that will be used to assess the effectiveness of the hedge. Any hedge ineffectiveness is recognized immediately in earnings, as are any gains and losses on the derivative that are excluded from the assessment of hedge effectiveness. The Partnership does not apply hedge accounting if it is determined that the hedge was not effective or will no longer be effective, the derivative was sold or exercised, or the hedged item was sold, repaid or no longer possible of occurring. For derivative financial instruments designated and qualifying as cash flow hedges, changes in the fair value of the effective portion of the derivative financial instruments are initially recorded as a component of accumulated other comprehensive income (loss) in total equity. In the periods when the hedged items affect earnings, the associated fair value changes on the hedging derivatives are transferred from total equity to the corresponding earnings line item in the consolidated statements of income. The ineffective portion of the change in fair value of the derivative financial instruments is immediately recognized in earnings in the consolidated statements of income. If a cash flow hedge is terminated and the originally hedged item is still considered possible of occurring, the gains and losses initially recognized in total equity remain there until the hedged item impacts earnings, at which point they are transferred to the corresponding earnings line item (e.g. interest expense) in the consolidated statements of income. If the hedged items are no longer possible of occurring, amounts recognized in total equity are immediately transferred to the earnings item in the consolidated statements of income. For derivative financial instruments that are not designated or that do not qualify as hedges under Financial Accounting Standards Board (or FASB ) Accounting Standards Codification (or ASC ) 815, Derivatives and Hedging , the changes in the fair value of the derivative financial instruments are recognized in earnings. Gains and losses from the Partnership’s non-designated interest rate swaps, interest rate swaptions, and the Partnership’s agreement with Teekay Corporation for the Suezmax tanker the Toledo Spirit (see Note 11c) are recorded in realized and unrealized loss on non-designated derivative instruments in the Partnership’s consolidated statements of income. Gains and losses from the Partnership’s cross currency swaps are recorded in foreign exchange gain in the Partnership’s consolidated statements of income. Unit-based compensation The Partnership grants restricted unit awards as incentive-based compensation under the Teekay LNG Partners L.P. 2005 Long-Term Incentive Plan to certain of the Partnership’s employees and to certain employees of Teekay Corporation’s subsidiaries that provide services to the Partnership and its subsidiaries. The Partnership measures the cost of such awards using the grant date fair value of the award and recognizes that cost, net of estimated forfeitures, over the requisite service period. The requisite service period consists of the period from the grant date of the award to the earlier of the date of vesting or the date the recipient becomes eligible for retirement. For unit-based compensation awards subject to graded vesting, the Partnership calculates the value for the award as if it was one single award with one expected life and amortizes the calculated expense for the entire award on a straight-line basis over the requisite service period. The compensation cost of the Partnership’s unit-based compensation awards are reflected in general and administrative expenses in the Partnership’s consolidated statements of income. Income taxes The Partnership accounts for income taxes using the liability method. All but two of the Partnership’s Spanish-flagged vessels are subject to the Spanish Tonnage Tax Regime (or TTR ). Under this regime, the applicable tax is based on the weight (measured as net tonnage) of the vessel and the number of days during the taxable period that the vessel is at the Partnership’s disposal, excluding time required for repairs. The income the Partnership receives with respect to the remaining two Spanish-flagged vessels is taxed in Spain at a rate of 25% . However, these two vessels are registered in the Canary Islands Special Ship Registry. Consequently, the Partnership is allowed a credit, equal to 90% of the tax payable on income from the commercial operation of these vessels, against the tax otherwise payable. This effectively results in an income tax rate of approximately 2.5% on income from the operation of these two Spanish-flagged vessels. The Partnership recognizes the benefits of uncertain tax positions when it is more-likely-than-not that a tax position taken or expected to be taken in a tax return will be sustained upon examination, including resolution of any related appeals or litigation processes, based on the technical merits of the position. If a tax position meets the more-likely-than-not recognition threshold, it is measured to determine the amount of benefit to recognize in the financial statements. The Partnership recognizes interest and penalties related to uncertain tax positions in income tax expense in the Partnership’s consolidated statements of income. Guarantees Guarantees issued by the Partnership, excluding those that are guaranteeing its own performance, are recognized at fair value at the time the guarantees are issued and are presented in the Partnership’s consolidated balance sheets as other long-term liabilities. The liability recognized on issuance is amortized to other income on the Partnership’s consolidated statements of income over the term of the guarantee. If it becomes probable that the Partnership will have to perform under a guarantee, the Partnership will recognize an additional liability if the amount of the loss can be reasonably estimated. Accumulated other comprehensive income (loss) The following table contains the changes in the balance of the Partnership’s only component of accumulated other comprehensive income (loss) for the periods presented: Qualifying Cash Balance as at December 31, 2013 131 Other comprehensive loss (1,534 ) Balance as at December 31, 2014 (1,403 ) Other comprehensive loss (648 ) Balance as at December 31, 2015 (2,051 ) Other comprehensive income 2,626 Balance as at December 31, 2016 575

Accounting Pronouncements

Accounting Pronouncements	12 Months Ended
	Dec. 31, 2016
Accounting Changes and Error Corrections [Abstract]
Accounting Pronouncements	Accounting Pronouncements In May 2014, the FASB issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers , (or ASU 2014-09 ). ASU 2014-09 will require an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This update creates a five-step model that requires entities to exercise judgment when considering the terms of the contract(s) which include (i) identifying the contract(s) with the customer, (ii) identifying the separate performance obligations in the contract, (iii) determining the transaction price, (iv) allocating the transaction price to the separate performance obligations, and (v) recognizing revenue as each performance obligation is satisfied. ASU 2014-09 is effective for the Partnership on January 1, 2018 and shall be applied, at the Partnership’s option, retrospectively to each period presented or as a cumulative-effect adjustment as of the date of adoption. The Partnership’s only significant source of revenue that will be accounted for pursuant to ASU 2014-09 is its non-lease portion of time-charter contracts. Based on the Partnership’s preliminary assessment of ASU 2014-09, when applied to the standard terms of the Partnership’s time-charter contracts, no significant impact on the accounting for the non-lease portion of time-charter contracts is expected. The Partnership is in the process of validating aspects of its preliminary assessment of ASU 2014-09, determining the transitional impact and completing other items required for the adoption of ASU 2014-09. In February 2016, the FASB issued Accounting Standards Update 2016-02, Leases (or ASU 2016-02 ). ASU 2016-02 establishes a right-of-use model that requires a lessee to record a right of use asset and a lease liability on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The Partnership expects to adopt ASU 2016-02 on January 1, 2018. A modified retrospective transition approach is required for lessees for capital and operating leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements, with certain practical expedients available. The Partnership’s lessee-related leasing activities primarily consist of on-balance sheet finance leases. The accounting for such transactions is not significantly impacted by ASU 2016-02. The Partnership also has extensive lessor-related leasing activities, which consist of bareboat charter contracts and the lease portion of time-charter contracts. However, ASU 2016-02 does not make extensive changes to lessor accounting. Based on the Partnership’s preliminary assessment of ASU 2016-02 no significant impact on the accounting for its lessor-related leasing activities is expected. The Partnership is in the process of validating aspects of its preliminary assessment of ASU 2016-02, determining the transitional impact and completing other items required for the adoption of ASU 2016-02. In June 2016, the FASB issued Accounting Standards Update 2016-13, Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Instruments . This update replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. This update is effective for the Partnership January 1, 2020, with a modified-retrospective approach. The Partnership is currently evaluating the effect of adopting this new guidance. In August 2016, the FASB issued Accounting Standards Update 2016-15, Statement of Cash Flows: Classification of Certain Cash Receipts and Cash Payments , which, among other things, provides guidance on two acceptable approaches of classifying distributions received from equity method investees in the statement of cash flows. This update is effective for the Partnership January 1, 2018, with a retrospective approach. The Partnership is currently evaluating the effect of adopting this new guidance.

Financial Instruments

Financial Instruments	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Financial Instruments	Financial Instruments a) Fair Value Measurements The following methods and assumptions were used to estimate the fair value of each class of financial instrument: Cash and cash equivalents and restricted cash – The fair value of the Partnership’s cash and cash equivalents and restricted cash approximates its carrying amounts reported in the consolidated balance sheets. Interest rate swap/swaption and cross-currency swap agreements – The fair value of the Partnership’s derivative instruments 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 derivative counterparties. The estimated amount is the present value of future cash flows. The Partnership transacts all of its derivative instruments through investment-grade rated financial institutions at the time of the transaction and requires no collateral from these institutions. Given the current volatility in the credit markets, it is reasonably possible that the amount recorded as a derivative asset or liability could vary by a material amount in the near term. Other derivative – The Partnership’s other derivative agreement is between Teekay Corporation and the Partnership and relates to hire payments under the time-charter contract for the Suezmax tanker Toledo Spirit (see Note 11c). The fair value of this derivative agreement is the estimated amount that the Partnership would receive or pay to terminate the agreement at the reporting date, based on the present value of the Partnership’s projection of future spot market tanker rates, which have been derived from current spot market tanker rates and long-term historical average rates. As projections of future spot rates are specific to the Partnership, these are considered Level 3 inputs for the purposes of estimating the fair value. Long-term receivable included in accounts receivable and other assets – The fair values of the Partnership’s long-term loan receivable is estimated using discounted cash flow analysis based on rates currently available for debt with similar terms and remaining maturities and the current credit worthiness of the counterparty. Long-term debt – The fair values of the Partnership’s fixed-rate and variable-rate long-term debt is either based on quoted market prices or estimated using discounted cash flow analyses based on rates currently available for debt with similar terms and remaining maturities and the current credit worthiness of the Partnership. The Partnership categorizes the fair value estimates by a fair value hierarchy based on the inputs used to measure fair value. 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 includes the estimated fair value and carrying value of those assets and liabilities that are measured at fair value on a recurring and non-recurring basis, as well as the estimated fair value of the Partnership’s financial instruments that are not accounted for at a fair value on a recurring basis. December 31, 2016 December 31, 2015 Fair Value Carrying Fair Carrying Fair Recurring: Cash and cash equivalents and restricted cash Level 1 243,173 243,173 214,000 214,000 Derivative instruments (note 12) Interest rate swap agreements – assets Level 2 1,080 1,080 — — Interest rate swap agreements – liabilities Level 2 (87,681 ) (87,681 ) (104,137 ) (104,137 ) Interest rate swaption agreements – assets Level 2 3,283 3,283 5,623 5,623 Interest rate swaption agreements – liabilities Level 2 (4,230 ) (4,230 ) (6,406 ) (6,406 ) Cross-currency swap agreements Level 2 (99,786 ) (99,786 ) (128,782 ) (128,782 ) Other derivative Level 3 2,134 2,134 (6,296 ) (6,296 ) Non-recurring: Vessel held for sale Level 2 20,580 20,580 — — Other: Advances to equity accounted joint ventures (note 6) (i) 272,514 (i) 159,870 (i) Long-term receivable included in accounts receivable and other assets (ii) Level 3 10,985 10,944 16,453 16,427 Long-term debt – public (note 9) Level 1 (368,612 ) (366,418 ) (291,247 ) (288,333 ) Long-term debt – non-public (note 9) Level 2 (1,422,614 ) (1,381,287 ) (1,707,962 ) (1,677,139 ) (i) The advances to equity accounted joint ventures together with the Partnership’s equity investments in the joint ventures form the net aggregate carrying value of the Partnership’s interests in the joint ventures in these consolidated financial statements. The fair values of the individual components of such aggregate interests are not determinable. (ii) As at December 31, 2016 , the estimated fair value of the non-interest bearing receivable is based on the remaining future fixed payments of $10.9 million to be received from Royal Dutch Shell Plc (or Shell ) (formerly BG International Limited (or BG )), as part of the ship construction support agreement, as well as an estimated discount rate of 8.0% . As there is no market rate for the equivalent of an unsecured non-interest bearing receivable from Shell, the discount rate is based on unsecured debt instruments of similar maturity held, adjusted for a liquidity premium. A higher or lower discount rate would result in a lower or higher fair value asset. Changes in fair value during the years ended December 31, 2016 and 2015 for the Partnership’s other derivative asset, the Toledo Spirit time-charter derivative, which is described below and is measured at fair value on a recurring basis using significant unobservable inputs (Level 3), are as follows: Year Ended December 31, 2016 2015 Fair value at beginning of year (6,296 ) (2,137 ) Realized and unrealized gains (losses) included in earnings 3,316 (5,039 ) Settlements 5,114 880 Fair value at end of year 2,134 (6,296 ) The Partnership’s Suezmax tanker the Toledo Spirit operates pursuant to a time-charter contract that increases or decreases the otherwise fixed-hire rate established in the charter depending on the spot charter rates that the Partnership would have earned had it traded the vessel in the spot tanker market. The time-charter contract ends in August 2025, although the charterer has the right to terminate the time-charter contract in July 2018. In order to reduce the variability of its revenue under the Toledo Spirit time-charter, the Partnership entered into an agreement with Teekay Corporation under which Teekay Corporation pays the Partnership any amounts payable to the charterer of the Toledo Spirit as a result of spot rates being below the fixed rate, and the Partnership pays Teekay Corporation any amounts payable to the Partnership by the charterer of the Toledo Spirit as a result of spot rates being in excess of the fixed rate. The estimated fair value of this other derivative is based in part upon the Partnership’s projection of future spot market tanker rates, which has been derived from current spot market tanker rates and long-term historical average rates as well as an estimated discount rate. The estimated fair value of this other derivative as of December 31, 2016 is based upon an average daily tanker rate of $22,875 ( December 31, 2015 – $34,093 ) over the remaining duration of the charter contract and a discount rate of 8.4% ( December 31, 2015 – 7.5% ). In developing and evaluating this estimate, the Partnership considers the current tanker market fundamentals as well as the short and long-term outlook. A higher or lower average daily tanker rate would result in a higher or lower fair value liability or a lower or higher fair value asset. A higher or lower discount rate would result in a lower or higher fair value asset or liability. b) Financing Receivables The following table contains a summary of the Partnership’s loan receivables and other financing receivables by type of borrower and the method by which the Partnership monitors the credit quality of its financing receivables on a quarterly basis. Class of Financing Receivable Credit Quality Indicator Grade December 31 December 31 Direct financing leases Payment activity Performing 643,008 666,658 Other receivables: Long-term receivable and accrued revenue included in accounts receivable and other assets Payment activity Performing 12,171 28,256 Advances to equity accounted joint ventures Other internal metrics Performing 272,514 159,870 927,693 854,784

Segment Reporting

Segment Reporting	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Reporting	Segment Reporting The Partnership has two reportable segments, its liquefied gas segment and its conventional tanker segment. The Partnership’s liquefied gas segment consists of LNG carriers, LPG carriers and multigas carriers, which can carry both LNG and LPG, which generally operate under long-term, fixed-rate charters to international energy companies and Teekay Corporation (see Note 11a). As at December 31, 2016 , the Partnership’s liquefied gas segment consisted of 50 LNG carriers and LNG carrier newbuildings (including 26 LNG carriers and LNG carrier newbuildings included in joint ventures that are accounted for under the equity method), and 29 LPG/Multigas carriers and LPG carrier newbuildings (including 23 LPG carriers and LPG carrier newbuildings included in a joint venture that is accounted for under the equity method). As at December 31, 2016 , the Partnership’s conventional tanker segment consisted of five Suezmax-class crude oil tankers and one Handymax product tanker. 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 table presents voyage revenues and percentage of consolidated voyage revenues for the Partnership’s customers who accounted for 10% or more of the Partnership's consolidated voyage revenues during any of the periods presented. (U.S. Dollars in millions) Year Ended Year Ended Year Ended Ras Laffan Liquefied Natural Gas Company Ltd. (i) $70.3 or 18% $70.1 or 18% $69.8 or 17% Shell Spain LNG S.A.U. (i),(ii) $48.2 or 12% $48.5 or 12% $51.8 or 13% The Tangguh Production Sharing Contractors (i) $44.4 or 11% $44.9 or 11% $44.3 or 11% (i) Liquefied gas segment. (ii) Shell Spain LNG S.A.U. acquired the charter contracts from Repsol YPF, S.A. in March 2014. The voyage revenues in 2014 consisted of the voyage revenues from both customers relating to the same charter contract. The following tables include results for these segments for the years presented in these financial statements. Year Ended December 31, 2016 Liquefied Gas Conventional Total Voyage revenues 336,530 59,914 396,444 Voyage expenses (449 ) (1,207 ) (1,656 ) Vessel operating expenses (66,087 ) (22,503 ) (88,590 ) Depreciation and amortization (80,084 ) (15,458 ) (95,542 ) General and administrative expenses (i) (15,310 ) (3,189 ) (18,499 ) Write-down and loss on sale of vessels — (38,976 ) (38,976 ) Income (loss) from vessel operations 174,600 (21,419 ) 153,181 Equity income 62,307 — 62,307 Investment in and advances to equity accounted joint ventures 1,037,726 — 1,037,726 Total assets at December 31, 2016 3,957,088 193,553 4,150,641 Expenditures for vessels and equipment (344,924 ) (63 ) (344,987 ) Expenditures for dry docking (13,944 ) — (13,944 ) Year Ended December 31, 2015 Liquefied Gas Conventional Total Voyage revenues 305,056 92,935 397,991 Voyage recoveries (expenses) 203 (1,349 ) (1,146 ) Vessel operating expenses (63,344 ) (30,757 ) (94,101 ) Depreciation and amortization (71,323 ) (20,930 ) (92,253 ) General and administrative expenses (i) (19,392 ) (5,726 ) (25,118 ) Restructuring charges — (4,001 ) (4,001 ) Income from vessel operations 151,200 30,172 181,372 Equity income 84,171 — 84,171 Investment in and advances to equity accounted joint ventures 883,731 — 883,731 Total assets at December 31, 2015 3,550,396 360,527 3,910,923 Expenditures for vessels and equipment (191,642 ) (327 ) (191,969 ) Expenditures for dry docking (8,659 ) (1,698 ) (10,357 ) Year Ended December 31, 2014 Liquefied Gas Conventional Total Voyage revenues 307,426 95,502 402,928 Voyage expenses (1,768 ) (1,553 ) (3,321 ) Vessel operating expenses (59,087 ) (36,721 ) (95,808 ) Depreciation and amortization (71,711 ) (22,416 ) (94,127 ) General and administrative expenses (i) (17,992 ) (5,868 ) (23,860 ) Restructuring charges — (1,989 ) (1,989 ) Income from vessel operations 156,868 26,955 183,823 Equity income 115,478 — 115,478 Expenditures for vessels and equipment (193,669 ) (586 ) (194,255 ) Expenditures for dry docking (8,127 ) (5,344 ) (13,471 ) (i) Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to each segment based on estimated use of corporate resources). A reconciliation of total segment assets presented in the consolidated balance sheets is as follows: December 31 December 31 Total assets of the liquefied gas segment 3,957,088 3,550,396 Total assets of the conventional tanker segment 193,553 360,527 Unallocated: Cash and cash equivalents 126,146 102,481 Accounts receivable and prepaid expenses 28,948 26,550 Advances to affiliates 9,739 13,026 Consolidated total assets 4,315,474 4,052,980

Leases and Restricted Cash

Leases and Restricted Cash	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Leases and Restricted Cash	Leases and Restricted Cash Capital Lease Obligations December 31 December 31 LNG Carriers 338,257 — Suezmax Tankers 54,582 59,127 Total obligations under capital lease 392,839 59,127 Less current portion (40,353 ) (4,546 ) Long-term obligations under capital lease 352,486 54,581 LNG Carriers. As at December 31, 2016 , the Partnership was a party to capital leases on two LNG carriers, the Creole Spirit and Oak Spirit . Upon delivery of the Creole Spirit in February 2016 and the Oak Spirit in July 2016, the Partnership sold these vessels to a third party and leased them back under 10 -year bareboat charter contracts ending in 2026. The bareboat charter contracts are fixed-rate capital leases with a fixed-price purchase obligation at the end of the lease terms. At inception of these leases, the weighted-average interest rate implicit in these leases was 5.5% . The Partnership guarantees the obligations of the bareboat charter contracts. In addition, the guarantee agreements require the Partnership to maintain minimum levels of tangible net worth and aggregate liquidity, and not to exceed a maximum amount of leverage. In December 2016, the Partnership entered into a $682.8 million sale-leaseback agreement for four of the Partnership’s LNG carrier newbuildings equipped with the M-type, Electronically Controlled, Gas Injection (or MEGI ) twin engines, delivering in 2017 and 2018, and at such dates, the buyer will take delivery and charter each respective vessel back to the Partnership. As at December 31, 2016 , the remaining commitments under the two capital leases for the Creole Spirit and the Oak Spirit , including the related purchase obligations, approximated $478.1 million , including imputed interest of $139.8 million , repayable from 2017 through 2026, as indicated below: Year Commitment 2017 $ 30,065 2018 $ 30,065 2019 $ 30,065 2020 $ 30,147 2021 $ 30,065 Thereafter $ 327,686 Suezmax Tankers. As at December 31, 2016 , the Partnership was a party to capital leases on two Suezmax tankers. Under these capital leases, the owner has the option to require the Partnership to purchase the two vessels. The charterer, who is also the owner, also has the option to cancel the charter contracts and the cancellation options are first exercisable in October 2017 and July 2018, respectively. The amounts in the table below assume the owner will not exercise its options to require the Partnership to purchase either of the two remaining vessels from the owner, but rather it assumes the owner will cancel the charter contracts when the cancellation right is first exercisable (in October 2017 and July 2018, respectively) and sell the vessels to a third party, upon which the remaining lease obligations will be extinguished. At the inception of these leases, the weighted-average interest rate implicit in these leases was 5.5% . These capital leases are variable-rate capital leases. However, any change in the lease payments resulting from changes in interest rates is offset by a corresponding change in the charter hire payments received by the Partnership. As at December 31, 2016 , the remaining commitments under the two capital leases for Suezmax tankers, including the related purchase obligations, approximated $58.2 million , including imputed interest of $3.6 million , repayable from 2017 through 2018, as indicated below: Year Commitment 2017 $ 30,953 2018 $ 27,296 The Partnership’s capital leases relating to its Suezmax tankers do not contain financial or restrictive covenants other than those relating to operation and maintenance of the vessels. Restricted Cash The Partnership maintains restricted cash deposits relating to certain term loans, collateral for cross-currency swaps, project tenders, leasing arrangements (see Note 13c) and amounts received from charterers to be used only for dry-docking expenditures and emergency repairs, which cash totaled $117.0 million and $111.5 million as at December 31, 2016 and 2015 , respectively. Operating Lease Obligations Teekay Tangguh Joint Venture As at December 31, 2016 , the Teekay BLT Corporation (or the Teekay Tangguh Joint Venture ) was a party to operating leases (or Head Leases ) whereby it is leasing its two LNG carriers (or the Tangguh LNG Carriers ) to a third party company. The Teekay Tangguh Joint Venture is then leasing back the LNG carriers from the same third party company (or the Subleases ). Under the terms of these leases, the third party company claims tax depreciation on the capital expenditures it incurred to lease the vessels. As is typical in these leasing arrangements, tax and change of law risks are assumed by the Teekay Tangguh Joint Venture. Lease payments under the Subleases are based on certain tax and financial assumptions at the commencement of the leases. If an assumption proves to be incorrect, the lease payments are increased or decreased under the Sublease to maintain the agreed after-tax margin. The Teekay Tangguh Joint Venture’s carrying amounts of this tax indemnification guarantee as at December 31, 2016 and 2015 were $7.5 million and $8.0 million , respectively, and are included as part of other long-term liabilities in the consolidated balance sheets of the Partnership. The tax indemnification is for the duration of the lease contract with the third party plus the years it would take for the lease payments to be statute barred, and ends in 2033. Although there is no maximum potential amount of future payments, the Teekay Tangguh Joint Venture may terminate the lease arrangements on a voluntary basis at any time. If the lease arrangements terminate, the Teekay Tangguh Joint Venture will be required to make termination payments to the third party company sufficient to repay the third party company’s investment in the vessels and to compensate it for the tax effect of the terminations, including recapture of any tax depreciation. The Head Leases and the Subleases have 20 -year terms and are classified as operating leases. The Head Leases and the Subleases for the two Tangguh LNG Carriers commenced in November 2008 and March 2009, respectively. As at December 31, 2016 , the total estimated future minimum rental payments to be received and paid under the lease contracts are as follows: Year Head Lease Receipts (i) Sublease Payments (i) (ii) 2017 $ 21,242 $ 24,113 2018 $ 21,242 $ 24,113 2019 $ 21,242 $ 24,113 2020 $ 21,242 $ 24,113 2021 $ 21,242 $ 24,113 Thereafter $ 154,095 $ 174,959 Total $ 260,305 $ 295,524 (i) The Head Leases are fixed-rate operating leases while the Subleases have a small variable-rate component. As at December 31, 2016 , the Partnership had received $250.0 million of aggregate Head Lease receipts and had paid $187.9 million of aggregate Sublease payments. The portion of the Head Lease receipts that have not been recognized into earnings are deferred and amortized on a straight line basis over the lease terms and, as at December 31, 2016 , $3.7 million (December 31, 2015 – $3.8 million ) and $36.7 million (December 31, 2015 – $40.4 million ) of Head Lease receipts had been deferred and included in unearned revenue and other long-term liabilities, respectively, in the Partnership’s consolidated balance sheets. (ii) The amount of payments under the Subleases are updated annually to reflect any changes in the lease payments due to changes in tax law. Net Investments in Direct Financing Leases The Tangguh LNG Carriers commenced their time-charters with their charterers in January and May 2009, respectively. Both time-charters are accounted for as direct financing leases with 20-year terms. In September and November 2013, the Partnership acquired two 155,900 -cubic meter LNG carriers (or Awilco LNG Carriers ) from Norway-based Awilco LNG ASA (or Awilco ) and chartered them back to Awilco on five - and four -year fixed-rate bareboat charter contracts ( plus a one - year extension option ), respectively, with Awilco holding fixed-price purchase obligations at the end of the charter. The bareboat charters with Awilco are accounted for as direct financing leases. The purchase price of each vessel was $205.0 million less a $51.0 million upfront prepayment of charter hire by Awilco (inclusive of a $1.0 million upfront fee), which is in addition to the daily bareboat charter rate. The following table lists the components of the net investments in direct financing leases: December 31 December 31 Total minimum lease payments to be received 764,970 843,079 Estimated unguaranteed residual value of leased properties 194,965 194,965 Initial direct costs 393 425 Less unearned revenue (317,320 ) (371,811 ) Total net investments in direct financing leases 643,008 666,658 Less current portion (150,342 ) (20,606 ) Net investments in direct financing leases 492,666 646,052 As at December 31, 2016 , estimated minimum lease payments to be received by the Partnership under the Tangguh LNG Carrier leases in each of the next five succeeding fiscal years are approximately $39.1 million per year from 2017 through 2021. Both leases are scheduled to end in 2029. In addition, estimated minimum lease payments in the next two years to be received by the Partnership under the Awilco LNG Carrier leases are approximately $162.0 million ( 2017 ) and $134.6 million ( 2018 ). Operating Leases As at December 31, 2016 , the minimum scheduled future revenues to be received by the Partnership in each of the next five years for the lease and non-lease elements under charters that were accounted for as operating leases are approximately $349.2 million ( 2017 ), $372.2 million ( 2018 ), $404.0 million ( 2019 ), $393.3 million ( 2020 ), and $353.5 million ( 2021 ). Minimum scheduled future revenues do not include revenue generated from new contracts entered into after December 31, 2016 , revenue from vessels in the Partnership’s equity accounted investments, revenue from unexercised option periods of contracts that existed on December 31, 2016 , or variable or contingent revenues. Therefore, the minimum scheduled future revenues should not be construed to reflect total charter hire revenues for any of these five years.

Equity Accounted Investments

Equity Accounted Investments	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Accounted Investments	Equity Accounted Investments a) A summary of the Partnership's investments in and advances to equity accounted investees are as follows: As at December 31, Name Ownership Percentage # of Delivered Vessels Newbuildings on order 2016 2015 Bahrain LNG Joint Venture (i) 30% - 1 63,933 — Yamal LNG Joint Venture (ii) 50% - 6 152,702 99,886 BG Joint Venture (iii) 20%-30% - 4 33,860 25,574 Exmar LPG Joint Venture (iv) 50% 19 4 167,763 166,430 Teekay LNG-Marubeni Joint Venture (v) 52% 6 - 299,601 294,433 Excalibur and Excelsior Joint Ventures (vi) 49%-50% 2 - 79,577 77,845 Angola Joint Venture (vii) 33% 4 - 65,644 58,170 RasGas 3 Joint Venture (viii) 40% 4 - 174,646 161,393 35 15 1,037,726 883,731 (i) Bahrain LNG Joint Venture On December 2, 2015, the Partnership ( 30% ) entered into a joint venture agreement with National Oil & Gas Authority (or Nogaholding ) ( 30% ), Gulf Investment Corporation (or GIC ) ( 24% ) and Samsung C&T (or Samsung ) ( 16% ) to form a joint venture, Bahrain LNG W.L.L. (or the Bahrain LNG Joint Venture ), for the development of an LNG receiving and regasification terminal in Bahrain. The project will include an offshore LNG receiving jetty and breakwater, an adjacent regasification platform, subsea gas pipelines from the platform to shore, an onshore gas receiving facility, and an onshore nitrogen production facility with a total LNG terminal capacity of 800 million standard cubic feet per day and will be owned and operated under a 20 -year agreement commencing in early-2019. In addition, the Partnership will supply a floating storage unit (or FSU ) in connection with this project, which will be modified from one of the Partnership’s nine MEGI LNG carrier newbuildings ordered from Daewoo Shipbuilding & Marine Engineering Co. (or DSME ) (see Note 13a), through a 20 -year time-charter contract with the Bahrain LNG Joint Venture. As at December 31, 2016 , the Partnership had advanced $62.9 million ( December 31, 2015 – $ nil ) to the Bahrain LNG Joint Venture. These advances bear interest at LIBOR plus 1.25% and as at December 31, 2016 , the interest accrued on these advances was $0.1 million ( December 31, 2015 – $ nil ). These amounts are included in the table above. (ii) Yamal LNG Joint Venture On July 9, 2014, the Partnership entered into a 50 /50 joint venture (or the Yamal LNG Joint Venture ) with China LNG Shipping (Holdings) Limited and ordered six internationally-flagged icebreaker LNG carriers for a project located on the Yamal Peninsula in Northern Russia (or the Yamal LNG Project ). As at December 31, 2016 , the Partnership had advanced $146.7 million to the Yamal LNG Joint Venture ( December 31, 2015 – $96.9 million ). The advances bear interest at LIBOR plus 3.00% compounded semi-annually. As of December 31, 2016 , the interest accrued on these advances was $9.4 million ( December 31, 2015 – $4.8 million ). These amounts are included in the table above. (iii) BG Joint Venture On June 27, 2014, the Partnership acquired from BG (which was subsequently acquired by Shell) its ownership interests in four 174,000 -cubic meter Tri-Fuel Diesel Electric LNG carrier newbuildings, which will be constructed by Hudong-Zhonghua Shipbuilding (Group) Co., Ltd. in China for an estimated total fully built-up cost to the joint venture of approximately $1.0 billion . Through this transaction, the Partnership has a 30% ownership interest in two LNG carrier newbuildings and a 20% ownership interest in the remaining two LNG carrier newbuildings (or collectively, the BG Joint Venture ). As compensation for Shell’s ownership interest in these four LNG carrier newbuildings, the Partnership assumed Shell’s obligation to provide the shipbuilding supervision and crew training services for the four LNG carrier newbuildings up to their delivery date pursuant to a ship construction support agreement. The Partnership estimates it will incur approximately $36.9 million of costs to provide these services, of which Shell has agreed to pay a fixed amount of $20.3 million . The Partnership estimated that the fair value of the service obligation was $33.3 million and the fair value of the amount due from Shell was $16.5 million . As at December 31, 2016 , the carrying value of the service obligation of $22.6 million ( December 31, 2015 – $29.7 million ) is included in both the current portion of in-process contracts and in-process contracts and the carrying value of the receivable from Shell of $10.9 million ( December 31, 2015 – $16.5 million ) is included in both accounts receivable and other assets in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the BG Joint Venture's net assets was $16.8 million ( December 31, 2015 – $16.8 million ). This basis difference has been allocated notionally to the ship construction support agreements and the time-charter contracts. As at December 31, 2016 , to fund its newbuilding installments, the BG Joint Venture has drawn $221.0 million ( December 31, 2015 – $110.3 million ) from its $787.0 million long-term debt facility and received $16.6 million of capital contributions from the Partnership ( December 31, 2015 – $8.6 million ), representing the Partnership’s proportionate share. (iv) Exmar LPG Joint Venture The Partnership has a joint venture agreement with Exmar NV (or Exmar ). In June 2015, Exmar LPG BVBA (or the Exmar LPG Joint Venture ) completed a refinancing of its existing debt facility by entering into a $460.0 million long-term debt facility bearing interest at a rate of LIBOR plus 1.90% , maturing in 2021. The Partnership has guaranteed its 50% share of the secured loan facility in the Exmar LPG Joint Venture and, as a result, recorded a guarantee liability of $1.7 million . The carrying value of the guarantee liability as at December 31, 2016 was $1.3 million ( December 31, 2015 – $1.5 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the Partnership had advanced $52.3 million ( December 31, 2015 – $57.8 million ) to the Exmar LPG Joint Venture, which bears interest at LIBOR plus 0.50% and has no fixed repayment terms. As at December 31, 2016 , the interest accrued on these advances was $1.1 million ( December 31, 2015 – $0.4 million ). These amounts are included in the table above. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the Exmar LPG Joint Venture's net assets was $30.2 million ( December 31, 2015 – $36.4 million ). The basis difference has been accounted for as an adjustment to the value of the vessels and charter agreements of the Exmar LPG Joint Venture and recognition of goodwill in accordance with the finalized purchase price allocation. (v) Teekay LNG-Marubeni Joint Venture The Partnership has a joint venture with Marubeni Corporation and the Partnership (or the Teekay LNG-Marubeni Joint Ventur e). Since control of the Teekay LNG-Marubeni Joint Venture is shared jointly between Marubeni and the Partnership, the Partnership accounts for its investment in the Teekay LNG-Marubeni Joint Venture using the equity method. From June to July 2013, the Teekay LNG Marubeni Joint Venture completed a refinancing of its short-term loan facilities by entering into separate long-term debt facilities totaling approximately $963 million . These debt facilities mature between 2017 and 2030 (see Note 19e). The Partnership has guaranteed its 52% share of the secured loan facilities of the Teekay LNG-Marubeni Joint Venture and, as a result, recorded a guarantee liability of $0.7 million . The carrying value of the guarantee liability as at December 31, 2016 was $0.1 million ( December 31, 2015 – $0.2 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. (vi) Excalibur and Excelsior Joint Ventures The Partnership has joint ventures with Exmar (or the Excalibur Joint Venture and the Excelsior Joint Venture ). In February 2015, the Excalibur and Excelsior Joint Ventures completed refinancing of their existing debt facilities by entering into a $172.8 million long-term debt facility bearing interest at a rate of LIBOR plus 2.75% , maturing in 2019. The Partnership has guaranteed its 50% share of the secured loan facilities of the Excalibur and Excelsior Joint Ventures and, as a result, recorded a guarantee liability of $0.4 million . The carrying value of the guarantee liability as of December 31, 2016 was $0.2 million ( December 31, 2015 – $0.3 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the Excalibur and Excelsior Joint Venture's net assets was $37.2 million ( December 31, 2015 – $38.6 million ). The basis difference has substantially been accounted for as an increase to the carrying value of the vessels of the Excalibur and Excelsior Joint Ventures in accordance with the finalized purchase price allocation. (vii) Angola Joint Venture The Partnership has a 33% ownership interest in a joint venture (or the Angola Joint Venture ) that owns four 160,400 -cubic meter LNG carriers (or the Angola LNG Carriers ). The other partners of the Angola Joint Venture are NYK Energy Transport (or NYK ) ( 33% ) and Mitsui & Co. Ltd. ( 34% ). (viii) RasGas 3 Joint Venture The Partnership has a 40% ownership interest in Teekay Nakilat (III) Corporation (or the RasGas 3 Joint Venture ), and the remaining 60% is held by Qatar Gas Transport Company Ltd. (Nakilat). b) The RasGas 3 Joint Venture, the Excelsior Joint Venture, the Angola Joint Venture, the Yamal LNG Joint Venture, and the Bahrain LNG Joint Venture are considered variable interest entities; however, the Partnership is not the primary beneficiary and consolidation of these entities with the Partnership is not required. The Partnership’s maximum exposure to loss as a result of its investment in the RasGas 3 Joint Venture, the Excelsior Joint Venture, the Angola LNG Joint Venture, the Yamal LNG Joint Venture, and the Bahrain LNG Joint Venture is the amount it has invested and advanced in these joint ventures, which are $174.6 million , $50.3 million , $65.6 million , $152.7 million and $63.9 million , respectively, as at December 31, 2016 . In addition, the Partnership guarantees its portion of the Excelsior Joint Venture’s debt of $45.0 million and the Angola Joint Ventures’ debt and swaps of $256.1 million and provides a guarantee against a charter termination. The carrying value of Angola Joint Venture's guarantee liability as of December 31, 2016 was $1.0 million ( December 31, 2015 – $1.2 million ) and is included as part of other liabilities in the Partnership’s consolidated balance sheets. c) The follo wing table presents aggregated summarized financial information reflecting a 100% ownership interest in the Partnership’s equity method investments and excluding the impact from purchase price adjustments arising from the acquisition of Exmar LPG BVBA, the Excalibur and Excelsior Joint Ventures and the BG Joint Venture. The results include the Excalibur and Excelsior Joint Ventures, the RasGas 3 Joint Venture, the Angola Joint Venture, the Exmar LPG Joint Venture, the Teekay LNG-Marubeni Joint Venture, the BG Joint Venture from June 2014, the Yamal LNG Joint Venture from July 2014, and the Bahrain LNG Joint Venture from December 2015. As at December 31, 2016 2015 Cash and restricted cash – current 388,007 281,943 Other assets – current 111,847 77,861 Vessels and equipment 2,837,870 2,343,397 Net investments in direct financing leases – non-current 1,776,954 1,813,991 Other assets – non-current 37,132 22,120 Current portion of long-term debt and obligations under capital lease 209,814 166,522 Other liabilities – current 102,385 97,405 Long-term debt and obligations under capital lease 3,233,425 2,787,055 Other liabilities – non-current 157,025 177,879 Years ended December 31, 2016 2015 2014 Voyage revenues 549,646 596,093 640,105 Income from vessel operations 268,049 302,731 398,836 Realized and unrealized loss on non-designated derivative instruments (12,277 ) (25,108 ) (52,938 ) Net income 167,052 203,280 267,990

Intangible Assets and Goodwill

Intangible Assets and Goodwill	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets and Goodwill	Intangible Assets and Goodwill As at December 31, 2016 and 2015 , intangible assets consisted of acquired time-charter contracts with a weighted-average amortization period of 20.7 years . The carrying amount of intangible assets for the Partnership’s liquefied gas segment is as follows: December 31 December 31 Gross carrying amount 179,813 179,813 Accumulated amortization (109,879 ) (101,023 ) Net carrying amount 69,934 78,790 Amortization expense associated with intangible assets was $8.9 million , $8.9 million and $9.2 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. Amortization expense associated with intangible assets is expected to be approximately $8.9 million per year in each of the next five years. The carrying amount of goodwill as at each of December 31, 2016 and 2015 for the Partnership’s liquefied gas segment was $35.6 million . In 2016 and 2015 , the Partnership conducted its annual goodwill impairment review of its liquefied gas segment and concluded that no impairment had occurred.

Accrued Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2016
Payables and Accruals [Abstract]
Accrued Liabilities	Accrued Liabilities December 31 December 31 Interest including interest rate swaps 19,957 17,484 Voyage and vessel expenses 9,311 9,315 Payroll and benefits 3,355 5,431 Other general expenses 3,069 2,785 Income tax payable and other 189 2,441 Total 35,881 37,456

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt December 31, 2016 December 31, 2015 $ $ U.S. Dollar-denominated Revolving Credit Facilities due from 2017 to 2018 208,222 329,222 U.S. Dollar-denominated Term Loans due from 2018 to 2026 1,005,199 1,150,436 Norwegian Kroner-denominated Bonds due from 2017 to 2021 371,329 294,016 Euro-denominated Term Loans due from 2018 to 2023 219,733 241,798 Total principal 1,804,483 2,015,472 Unamortized discount and debt issuance costs (13,257 ) (16,263 ) Total debt 1,791,226 1,999,209 Less current portion (188,511 ) (197,197 ) Long-term debt 1,602,715 1,802,012 As at December 31, 2016 , the Partnership had three revolving credit facilities available of which two credit facilities are long-term and one is current. The three credit facilities, as at such date, provided for borrowings of up to $451.9 million (December 31, 2015 – $459.2 million ) , of which $243.7 million (December 31, 2015 – $130.0 million ) was undrawn. Interest payments are based on LIBOR plus margins, which ranged from 0.55% to 1.25% . The amount available under the three revolving credit facilities reduces by $198.2 million ( 2017 ) and $253.7 million ( 2018 ). The revolving credit facilities may be used by the Partnership to fund general partnership purposes and to fund cash distributions. The Partnership is required to repay all borrowings used to fund cash distributions within 12 months of their being drawn, from a source other than further borrowings. One of the revolving credit facilities is unsecured while the other two revolving credit facilities are collateralized by first-priority mortgages granted on four of the Partnership’s vessels, together with other related security, and include a guarantee from the Partnership or its subsidiaries of all outstanding amounts. As at December 31, 2016 , the Partnership had six U.S. Dollar-denominated term loans outstanding which totaled $1.0 billion in aggregate principal amount. Interest payments on the term loans are based on LIBOR plus a margin, which ranged from 0.30% to 2.80% . The six term loans require quarterly interest and principal payments and have balloon or bullet repayments due at maturity. The term loans are collateralized by first-priority mortgages on 15 of the Partnership’s vessels to which the loans relate, together with certain other related security. In addition, at December 31, 2016 , all of the outstanding term loans were guaranteed by either the Partnership or Teekay Nakilat Corporation (or the Teekay Nakilat Joint Venture ) , a joint venture in which the partnership has a 70% ownership interest and which owns three LNG carriers. The Partnership has Norwegian Kroner (or NOK ) 3.2 billion of senior unsecured bonds in the Norwegian bond market that mature through 2021. As at December 31, 2016 , the total amount of the bonds, which are listed on the Oslo Stock Exchange was $371.3 million . The interest payments on the bonds are based on NIBOR plus a margin, which ranges from 3.70% to 6.00% . The Partnership entered into cross-currency rate swaps, to swap all interest and principal payments of the bonds into U.S. Dollars, with the interest payments fixed at rates ranging from 5.92% to 7.72% and the transfer of principal fixed at $467 million upon maturity in exchange for NOK 3.2 billion (see Note 12). The Partnership has two Euro-denominated term loans outstanding, which as at December 31, 2016 , totaled 208.9 million Euros ( $219.7 million ). Interest payments are based on EURIBOR plus margins, which ranged from 0.60% to 2.25% as at December 31, 2016 , and the loans require monthly interest and principal payments. The term loans have varying maturities through 2023. The term loans are collateralized by first-priority mortgages on two vessels to which the loans relate, together with certain other related security and are guaranteed by the Partnership and one of its subsidiaries. The weighted-average effective interest rate for the Partnership’s long-term debt outstanding at December 31, 2016 and December 31, 2015 were 3.03% and 2.33% , respectively. These rates do not reflect the effect of related interest rate swaps that the Partnership has used to economically hedge certain of its floating-rate debt (see Note 12). At December 31, 2016 , the margins on the Partnership’s outstanding revolving credit facilities and term loans ranged from 0.30% to 2.80% . All Euro-denominated term loans and NOK-denominated bonds are revalued at the end of each period using the then-prevailing U.S. Dollar exchange rate. Due primarily to the revaluation of the Partnership’s NOK-denominated bonds, the Partnership’s Euro-denominated term loans and restricted cash, the repayment of the Partnership's NOK-denominated bonds and the termination of the associated cross-currency swaps, and the change in the valuation of the Partnership’s cross-currency swaps, the Partnership incurred foreign exchange gains of $5.3 million , $13.9 million , and $28.4 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. The aggregate annual long-term debt principal repayments required subsequent to December 31, 2016 are $190.1 million ( 2017 ), $719.8 million ( 2018 ), $82.5 million ( 2019 ), $178.0 million ( 2020 ), $288.4 million ( 2021 ) and $345.7 million ( thereafter ). Certain loan agreements require that (a) the Partnership maintains minimum levels of tangible net worth and aggregate liquidity, (b) the Partnership maintain certain ratios of vessel values related to the relevant outstanding loan principal balance, (c) the Partnership not exceed a maximum amount of leverage, and (d) certain of the Partnership’s subsidiaries maintains restricted cash deposits. As at December 31, 2016 , the Partnership had two facilities with an aggregate outstanding loan balance of $127.8 million that require it to maintain minimum vessel-value-to-outstanding-loan-principal-balance ratios ranging from 110% to 115% , which as at December 31, 2016 ranged from 133% to 209% . The vessel values were determined using second-hand market comparables or using a depreciated replacement cost approach. Since vessel values can be volatile, the Partnership’s estimates of market value may not be indicative of either the current or future prices that could be obtained if the Partnership sold any of the vessels. The Partnership’s ship-owning subsidiaries may not, among other things, pay dividends or distributions if the Partnership's subsidiaries are in default under their term loans or revolving credit facilities. As at December 31, 2016 , the Partnership was in compliance with all covenants relating to the Partnership’s credit facilities and term loans.

Income Tax

Income Tax	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Tax	Income Tax The components of the provision for income taxes were as follows: Year Ended Year Ended Year Ended Current (962 ) (2,646 ) (5,212 ) Deferred (11 ) (76 ) (2,355 ) Income tax expense (973 ) (2,722 ) (7,567 ) The Partnership operates in countries that have differing tax laws and rates. Consequently, a consolidated weighted average tax rate will vary from year to year according to the source of earnings or losses by country and the change in applicable tax rates. Reconciliations of the tax charge related to the relevant year at the applicable statutory income tax rates and the actual tax charge related to the relevant year are as follows: Year Ended Year Ended Year Ended Net income before income tax expenses 158,938 220,232 226,494 Net income not subject to taxes (138,542 ) (173,298 ) (81,604 ) Net income subject to taxes 20,396 46,934 144,890 At applicable statutory tax rates Amount computed using the standard rate of corporate tax (3,338 ) (12,007 ) (33,083 ) Adjustments to valuation allowance and uncertain tax positions 11,802 5,362 14,851 Permanent and currency differences (9,125 ) 4,204 11,507 Change in tax rate (312 ) (281 ) (842 ) Tax expense related to the current year (973 ) (2,722 ) (7,567 ) The significant components of the Partnership’s deferred tax assets (liabilities) were as follows: Year Ended Year Ended Derivative instruments 4,523 7,021 Taxation loss carryforwards and disallowed finance costs 34,927 44,823 Vessels and equipment 3,554 3,462 Capitalized interest (2,027 ) (2,184 ) 40,977 53,122 Valuation allowance (41,064 ) (53,198 ) Net deferred tax liabilities included in accrued liabilities (87 ) (76 ) The Partnership had tax losses in the United Kingdom (or UK ) of $12.7 million as at December 31, 2016 (December 31, 2015 – $12.7 million ) that are available indefinitely for offset against future taxable income in the UK. The Partnership had tax losses and disallowed finance costs in Spain of 110.3 million Euros or approximately $116.1 million (December 31, 2015 – 110.3 million Euros or approximately $119.8 million ) and 34.6 million Euros or approximately $36.4 million (December 31, 2015 – 34.2 million Euros or approximately $37.2 million ), respectively, at December 31, 2016 that are available indefinitely for offset against future taxable income in Spain. During 2015, as a result of an audit performed by the Spanish tax authorities on the Partnership’s Spanish subsidiaries, the Partnership and the Spanish tax authorities reached an agreement to reduce the Partnership’s tax losses in Spain by 29.0 million Euros or approximately $30.5 million . The losses were subject to a full valuation allowance, and therefore no change in income tax expense or assets will occur as a result of this agreement. The Partnership also had tax losses in Luxembourg of 93.3 million Euros or approximately $98.1 million as at December 31, 2016 (December 31, 2015 – 120.9 million Euros or approximately $131.3 million ) that are available indefinitely for offset against taxable future income in Luxembourg. The Partnership recognizes interest and penalties related to uncertain tax positions in income tax expense. The tax years 2007 through 2016 currently remain open to examination by the major tax jurisdictions to which the Partnership is subject.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions a) Two of the Partnership’s LNG carriers, the Arctic Spirit and Polar Spirit , are employed on long-term charter contracts with subsidiaries of Teekay Corporation. In addition, the Partnership and certain of its operating subsidiaries have entered into services agreements with certain subsidiaries of Teekay Corporation pursuant to which the Teekay Corporation subsidiaries provide the Partnership and its subsidiaries with administrative, commercial, crew training, advisory, business development, technical and strategic consulting services. In addition, as part of the Partnership’s acquisition of its ownership interest in the BG Joint Venture (see Notes 6a iii and 13a iv), the Partnership entered into an agreement with a subsidiary of Teekay Corporation whereby Teekay Corporation’s subsidiary will, on behalf of the Partnership, provide shipbuilding supervision and crew training services for the four LNG carrier newbuildings in the BG Joint Venture up to their delivery date. All costs incurred by Teekay Corporation’s subsidiary will be charged to the Partnership and recorded as part of vessel operating expenses. Finally, the Partnership reimburses the General Partner for expenses incurred by the General Partner that are necessary for the conduct of the Partnership’s business. Such related party transactions were as follows for the periods indicated: Year Ended December 31 December 31 December 31 Voyage revenues (i) 37,336 35,887 37,596 Vessel operating expenses (20,438 ) (19,914 ) (12,703 ) General and administrative expenses (ii) (11,890 ) (14,485 ) (13,708 ) General and administrative expenses deferred and capitalized (iii) (571 ) — — (i) Commencing in 2008, the Arctic Spiri t and Polar Spirit were time-chartered to Teekay Corporation at a fixed-rate for a period of 10 years (plus options exercisable by Teekay Corporation to extend up to an additional 15 years ). (ii) Includes commercial, strategic, advisory, business development and administrative management fees charged by Teekay Corporation and reimbursements to Teekay Corporation and our General Partner for costs incurred on the Partnership’s behalf. (iii) Includes the Partnership's proportionate costs associated with the Bahrain LNG Joint Venture including pre-operation, engineering and financing-related expenses, of which $0.4 million was reimbursed by the Bahrain LNG Joint Venture during 2016. The net costs are recorded as part of investments in and advances to equity accounted joint ventures in the Partnership's consolidated balance sheets. b) In connection with the Partnership’s initial public offering in May 2005, the Partnership entered into an omnibus agreement with Teekay Corporation, the General Partner and other related parties governing, among other things, when the Partnership and Teekay Corporation may compete with each other and certain rights of first offer on LNG carriers and Suezmax tankers. In December 2006, the omnibus agreement was amended in connection with the initial public offering of Teekay Offshore Partners L.P. (or Teekay Offshore ). As amended, the agreement governs, among other things, when the Partnership, Teekay Corporation and Teekay Offshore may compete with each other and certain rights of first offer on LNG carriers, oil tankers, shuttle tankers, floating storage and offtake units and floating production, storage and offloading units. c) The Partnership’s Suezmax tanker the Toledo Spirit operates pursuant to a time-charter contract that increases or decreases the otherwise fixed-hire rate established in the charter depending on the spot charter rates that the Partnership would have earned had it traded the vessel in the spot tanker market. The time-charter contract ends in August 2025, although the charterer has the right to terminate the time-charter in July 2018. The Partnership has entered into an agreement with Teekay Corporation under which Teekay Corporation pays the Partnership any amounts payable to the charterer as a result of spot rates being below the fixed rate, and the Partnership pays Teekay Corporation any amounts payable to the Partnership as a result of spot rates being in excess of the fixed rate. The amounts receivable or payable to Teekay Corporation are settled at the end of each year (see Notes 3 and 12). d) On November 13, 2014, the Partnership acquired a 2003-built 10,200 cubic meter LPG carrier, the Norgas Napa , from I.M. Skaugen SE (or Skaugen ) for $27.0 million . The Partnership took delivery of the vessel on November 13, 2014 and chartered the vessel back to Skaugen on a bareboat contract for a period of five years at a fixed rate plus a profit share component based on a portion of the vessel’s earnings from the Skaugen’s Norgas pool in excess of the fixed charter rate. In connection with the acquisition of the Norgas Napa , the General Partner acquired a 1% ownership interest in the Norgas Napa from the Partnership for approximately $0.2 million . e) In March 2014, two interest rate swap agreements were novated from Teekay Corporation to the Partnership. Teekay Corporation concurrently paid the Partnership $3.0 million in cash consideration, which represented the estimated fair value of the interest rate swap liabilities on the novation date. f) The Partnership entered into services agreements with certain subsidiaries of Teekay Corporation pursuant to which the Teekay Corporation subsidiaries provide the Partnership with shipbuilding and site supervision services relating to nine LNG carrier newbuildings the Partnership has ordered ( December 31, 2015 – 11 LNG carrier newbuildings) (see Notes 13a i and ii). These costs are capitalized and included as part of advances on newbuilding contracts in the Partnership’s consolidated balance sheets. During the years ended 2016 , 2015 and 2014 , the Partnership incurred shipbuilding and site supervision costs with Teekay Corporation subsidiaries of $8.5 million , $4.3 million and $3.1 million , respectively. As at December 31, 2016 and 2015 , shipbuilding and site supervision costs provided by Teekay Corporation subsidiaries included in advances on newbuilding contracts in the Partnership's consolidated balance sheets totaled $10.1 million and $7.6 million , respectively. g) As at December 31, 2016 and 2015 , non-interest bearing advances to affiliates totaled $9.7 million and $13.0 million , respectively, and non-interest bearing advances from affiliates totaled $15.5 million and $23.0 million , respectively. These advances are unsecured and have no fixed repayment terms. Affiliates are entities that are under the same common control.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities The Partnership uses derivative instruments in accordance with its overall risk management policy. Foreign Exchange Risk From 2013 through 2016 , concurrently with the issuance of NOK 3.5 billion of senior unsecured bonds (see Note 9) during that time, the Partnership entered into cross-currency swaps, and pursuant to these swaps, the Partnership receives the principal amount in NOK on maturity dates of the swaps in exchange for payments of a fixed U.S. Dollar amount. In addition, the cross-currency swaps exchange a receipt of floating interest in NOK based on NIBOR plus a margin for a payment of U.S. Dollar fixed interest. The purpose of the cross-currency swaps is to economically hedge the foreign currency exposure on the payment of interest and principal of the Partnership’s NOK-denominated bonds due in 2017, 2018, 2020 and 2021, and to economically hedge the interest rate exposure. The following table reflects information relating to the cross-currency swaps as at December 31, 2016 . Floating Rate Receivable Principal Principal Reference Margin Fixed Rate Fair Value / Weighted- 408,500 72,946 NIBOR 5.25 % 6.88 % (26,417 ) 0.3 900,000 150,000 NIBOR 4.35 % 6.43 % (49,655 ) 1.7 1,000,000 134,000 NIBOR 3.70 % 5.92 % (19,900 ) 3.4 900,000 110,400 NIBOR 6.00 % 7.72 % (3,814 ) 4.8 (99,786 ) Interest Rate Risk 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 certain of its outstanding floating-rate debt. As at December 31, 2016 , the Partnership was committed to the following interest rate swap agreements: Interest Principal Fair Value / Weighted- Fixed Interest Rate (%) (i) LIBOR-Based Debt: U.S. Dollar-denominated interest rate swaps LIBOR 90,000 (5,748 ) 1.7 4.9 U.S. Dollar-denominated interest rate swaps LIBOR 100,000 (1,145 ) 0.0 5.3 U.S. Dollar-denominated interest rate swaps (ii) LIBOR 156,250 (26,765 ) 12.0 5.2 U.S. Dollar-denominated interest rate swaps (ii) LIBOR 53,557 (1,494 ) 4.6 2.8 U.S. Dollar-denominated interest rate swaps (iii) LIBOR 320,000 (17,079 ) 1.0 3.4 U.S. Dollar-denominated interest rate swaps (iv) LIBOR 108,333 (665 ) 2.0 1.7 U.S. Dollar-denominated interest rate swaps (v) LIBOR 197,629 590 9.2 2.3 EURIBOR-Based Debt: Euro-denominated interest rate swaps (vi) EURIBOR 219,733 (34,295 ) 4.0 3.1 (86,601 ) (i) Excludes the margins the Partnership pays on its floating-rate term loans, which, at December 31, 2016 , ranged from 0.30% to 2.80% . (ii) Principal amount reduces semi-annually. (iii) These interest rate swaps are being used to economically hedge expected interest payments on future debt that is planned to be outstanding from 2017 to 2024. These interest rate swaps are subject to mandatory early termination in 2017 and 2018 whereby the swaps will be settled based on their fair value at that time. (iv) Principal amount reduces quarterly. (v) Principal amount reduces quarterly commencing December 2017. (vi) Principal amount reduces monthly to 70.1 million Euros ( $73.7 million ) by the maturity dates of the swap agreements. During 2015, as part of its economic hedging program, the Partnership entered into three interest rate swaption agreements, whereby the Partnership has a one-time option (or Call Option ) to enter into an interest rate swap with a third party, and the third party has a one-time option (or Put Option ) to require the Partnership to enter into interest swap agreements. If the Partnership or the third parties exercises its options, there will be cash settlements for the fair value of the interest rate swap, in lieu of taking delivery of the actual interest rate swaps. At December 31, 2016 , the terms of the interest rate swaps underlying the interest rate swaptions were as follows: Interest Principal Option Fair Value / Remaining Interest Interest rate swaption - Call Option LIBOR 155,000 (i) April 28, 2017 31 7.5 3.3 Interest rate swaption - Put Option LIBOR 155,000 (i) April 28, 2017 (1,525 ) 7.5 2.2 Interest rate swaption - Call Option LIBOR 160,000 (ii) January 31, 2018 1,140 8.0 3.1 Interest rate swaption - Put Option LIBOR 160,000 (ii) January 31, 2018 (1,457 ) 8.0 2.0 Interest rate swaption - Call Option LIBOR 160,000 (iii) July 16, 2018 2,112 8.0 2.9 Interest rate swaption - Put Option LIBOR 160,000 (iii) July 16, 2018 (1,248 ) 8.0 1.8 (i) Amortizing every three months from $155.0 million in April 2017 to $85.4 million in October 2024. (ii) Amortizing every three months from $160.0 million in January 2018 to $82.5 million in January 2026. (iii) Amortizing every three months from $160.0 million in July 2018 to $82.5 million in July 2026. As at December 31, 2016 , the Partnership had multiple interest rate swaps, interest rate swaptions, and cross-currency swaps with the same counterparty that are subject to the same master agreement. Each of these master agreements provide for the net settlement of all swaps subject to that master agreement through a single payment in the event of default or termination of any one swap. The fair value of these derivative instruments are presented on a gross basis in the Partnership’s consolidated balance sheets. As at December 31, 2016 , these interest rate swaps, interest rate swaptions, and cross-currency swaps had an aggregate fair value assets of $4.2 million and an aggregate fair value liability of $173.6 million . As at December 31, 2016 , the Partnership had $37.8 million ( December 31, 2015 – $44.8 million ) on deposit as security for swap liabilities under certain master agreements. The deposit is presented in restricted cash – current and – long-term on the Partnership’s consolidated balance sheets. Credit Risk The Partnership is exposed to credit loss in the event of non-performance by the counterparties to the interest rate swap agreements. In order to minimize counterparty risk, the Partnership only enters into derivative transactions with counterparties that are rated investment grade by Standard & Poor’s or A3 or better by Moody’s at the time of the transactions. In addition, to the extent practical, interest rate swaps are entered into with different counterparties to reduce concentration risk. Other Derivatives In order to reduce the variability of its revenue, the Partnership has entered into an agreement with Teekay Corporation under which Teekay Corporation pays the Partnership any amounts payable to the charterer of the Toledo Spirit as a result of spot rates being below the fixed rate, and the Partnership pays Teekay Corporation any amounts payable to the Partnership by the charterer of the Toledo Spirit as a result of spot rates being in excess of the fixed rate. The fair value of the derivative asset at December 31, 2016 was $2.1 million ( December 31, 2015 – a liability of $6.3 million ). The following table presents the location and fair value amounts of derivative instruments, segregated by type of contract, on the Partnership’s consolidated balance sheets. Derivative Accrued Current Derivative As at December 31, 2016 Interest rate swap agreements — — 1,080 (5,514 ) (22,432 ) (59,735 ) Interest rate swaption agreements — 31 3,252 — (1,525 ) (2,705 ) Cross-currency swap agreements — — — (1,090 ) (32,843 ) (65,853 ) Toledo Spirit time-charter derivative 1,274 500 360 — — — 1,274 531 4,692 (6,604 ) (56,800 ) (128,293 ) As at December 31, 2015 Interest rate swap agreements — — — (6,833 ) (41,028 ) (56,276 ) Interest rate swaption agreements — — 5,623 — — (6,406 ) Cross-currency swap agreements — — — (1,181 ) (9,755 ) (117,846 ) Toledo Spirit time-charter derivative — — — (3,186 ) (1,300 ) (1,810 ) — — 5,623 (11,200 ) (52,083 ) (182,338 ) Realized and unrealized gains (losses) relating to non-designated interest rate swap agreements, interest rate swaption agreements, and the Toledo Spirit time-charter derivative are recognized in earnings and reported in realized and unrealized loss on non-designated derivative instruments in the Partnership’s consolidated statements of income. The effect of the gain (loss) on these derivatives on the Partnership’s consolidated statements of income is as follows: Year Ended December 31, 2016 2015 2014 Realized Unrealized Total Realized Unrealized Total Realized Unrealized Total Interest rate swap agreements (25,940 ) 15,627 (10,313 ) (28,968 ) 14,768 (14,200 ) (39,406 ) 4,204 (35,202 ) Interest rate swaption agreements — (164 ) (164 ) — (783 ) (783 ) — — — Interest rate swap agreements termination — — — — — — (2,319 ) — (2,319 ) Toledo Spirit time-charter derivative (654 ) 3,970 3,316 (3,429 ) (1,610 ) (5,039 ) (861 ) (6,300 ) (7,161 ) (26,594 ) 19,433 (7,161 ) (32,397 ) 12,375 (20,022 ) (42,586 ) (2,096 ) (44,682 ) Unrealized and realized gains (losses) relating to cross-currency swap agreements are recognized in earnings and reported in foreign currency exchange gain in the Partnership’s consolidated statements of income. The effect of the gain (loss) on these derivatives on the Partnership's consolidated statements of income is as follows: Year Ended December 31, 2016 2015 2014 Realized Unrealized Total Realized Unrealized Total Realized Unrealized Total Cross-currency swap agreements (9,063 ) 28,905 19,842 (7,640 ) (57,759 ) (65,399 ) (2,222 ) (51,762 ) (53,984 ) Cross-currency swap agreements termination (17,711 ) — (17,711 ) — — — — — — (26,774 ) 28,905 2,131 (7,640 ) (57,759 ) (65,399 ) (2,222 ) (51,762 ) (53,984 ) For the year ended December 31, 2016 (no activity for the years ended December 31, 2015 and 2014 ), the following table presents the effective and ineffective portion of losses on interest rate swap agreements designated and qualifying as cash flow hedges. The following table excludes any interest rate swap agreements designated and qualifying as cash flow hedges in the Partnership’s equity accounted joint ventures. Year Ended December 31, 2016 Effective Portion Recognized in AOCI (i) $ Effective Portion Reclassified from AOCI (ii) $ Ineffective Portion (iii) $ 590 — — Interest expense 590 — — (i) Effective portion of designated and qualifying cash flow hedges recognized in other comprehensive income (loss). (ii) Effective portion of designated and qualifying cash flow hedges recorded in accumulated other comprehensive income (loss) (or AOCI ) during the term of the hedging relationship and reclassified to earnings. (iii) Ineffective portion of designated and qualifying cash flow hedges.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies a) The Partnership’s share of commitments to fund newbuilding and other construction contract costs as at December 31, 2016 are as follows: Total 2017 2018 2019 2020 DSME (i) 1,118,345 627,181 491,164 — — Hyundai Samho Heavy Industries Co. (ii) 378,347 82,507 45,533 250,307 — Yamal LNG Joint Venture (iii) 883,030 91,800 344,850 247,800 198,580 BG Joint Venture (iv) 195,565 80,010 86,154 29,401 — Bahrain LNG Joint Venture (v) 224,080 110,364 80,097 33,619 — Exmar LPG Joint Venture (vi) 77,504 58,096 19,408 — — 2,876,871 1,049,958 1,067,206 561,127 198,580 (i) As at December 31, 2016 , the Partnership had seven LNG carrier newbuildings on order with DSME which are scheduled for delivery between 2017 and 2019. As at December 31, 2016 , costs incurred under these newbuilding contracts totaled $316.1 million . The Partnership has secured $682.8 million of financing during 2016 related to the commitments for four LNG carrier newbuildings included in the table above (see Note 5) and in April 2017, secured $174.3 million of additional financing for one LNG carrier newbuilding included in the table above. (ii) As at December 31, 2016 , the Partnership had two LNG carrier newbuildings on order with Hyundai Samho Heavy Industries Co. (or HHI ) scheduled for delivery in 2019. As at December 31, 2016 , costs incurred under these newbuilding contracts totaled $41.5 million . The Partnership intends to finance the newbuilding payments through existing liquidity and expects to secure long-term debt financing for the vessels prior to their scheduled deliveries. (iii) The Partnership, through the Yamal LNG Joint Venture, has a 50% ownership interest in six 172,000 -cubic meter ARC7 LNG carrier newbuildings that have an estimated total fully built-up cost of $2.1 billion . As at December 31, 2016 , the Partnership’s proportionate costs incurred under these newbuilding contracts totaled $153.3 million . The Yamal LNG Joint Venture intends to secure debt financing for the six LNG carrier newbuildings prior to their scheduled deliveries. (iv) The Partnership acquired an ownership interest in the BG Joint Venture and, as part of the acquisition, agreed to assume Shell’s obligation to provide shipbuilding supervision and crew training services for the four LNG carrier newbuildings up to their delivery dates pursuant to a ship construction support agreement. The BG Joint Venture has secured financing of $137.1 million related to the commitments included in the table above and the Partnership is scheduled to receive $10.9 million of reimbursement directly from Shell. (v) The Partnership has a 30% ownership interest in the Bahrain LNG Joint Venture for the development of an LNG receiving and regasification terminal in Bahrain. The project will include a FSU, which will be modified from one of the Partnership’s existing MEGI LNG carrier newbuildings, an offshore gas receiving facility, and an onshore nitrogen production facility. The terminal will have a capacity of 800 million standard cubic feet per day and will be owned and operated under a 20 -year agreement commencing early-2019. The receiving and regasification terminal is expected to have a fully-built up cost of approximately $960.0 million . The Bahrain LNG Joint Venture has secured debt financing for approximately 75% of the estimated fully built-up cost of the LNG receiving and regasification terminal in Bahrain. (vi) The Partnership has a 50% ownership interest in the Exmar LPG Joint Venture which has four LPG newbuilding vessels scheduled for delivery between 2017 and 2018 and has secured financing for the four LPG carrier newbuildings. b) As of December 31, 2016, the Partnership adopted the new accounting standard ASC-205-40, Presentation of Financial Statements - Going Concern , which requires management to assess if the Partnership will have sufficient liquidity to continue as a going concern for the one-year period following the issuance of its financial statements. The Partnership anticipates making payments related to commitments to fund its wholly-owned vessels under construction of $709.7 million during 2017 and $536.7 million during 2018 as well as other payments relating to its joint ventures (see Note 13a). Based on these factors, over the one-year period following the issuance of its financial statements, the Partnership will need to obtain additional sources of financing, in addition to amounts generated from operations, to meet its minimum liquidity requirements under its financial covenants. These anticipated sources of financing include refinancing a loan facility maturing in the fourth quarter of 2017 as well as obtaining new debt financing for the unfinanced portion of its vessels under construction. The Partnership is actively pursuing the alternatives described above, which it considers probable of completion based on the Partnership’s history of being able to refinance similar loan facilities and to obtain new debt financing for its vessels under construction, as well as the progress it has made on the financing process to date. The Partnership is in various stages of completion with respect to its anticipated new financing facilities. Based on the Partnership’s liquidity at the date these consolidated financial statements were issued, the liquidity it expects to generate from operations over the following year, and by incorporating the Partnership’s plans to raise additional liquidity that it considers probable of completion, the Partnership estimates that it will have sufficient liquidity to continue as a going concern for at least the one-year period following the issuance of these consolidated financial statements. c) The Partnership owns a 70% ownership interest in the Teekay Nakilat Joint Venture, which was the lessee under three separate 30 -year capital lease arrangements with a third party for three LNG carriers (or the RasGas II LNG Carriers ). Under the terms of the leasing arrangements for the RasGas II LNG Carriers, the lessor claimed tax depreciation on the capital expenditures it incurred to acquire these vessels. As is typical in these leasing arrangements, tax and change of law risks were assumed by the lessee, in this case the Teekay Nakilat Joint Venture. Lease payments under the lease arrangements were based on certain tax and financial assumptions at the commencement of the leases and subsequently adjusted to maintain the lessor’s agreed after-tax margin. On December 22, 2014, the Teekay Nakilat Joint Venture terminated the leasing of the RasGas II LNG Carriers. However, the Teekay Nakilat Joint Venture remains obligated to the lessor to maintain the lessor’s agreed after-tax margin from the commencement of the lease to the lease termination date and placed $6.8 million on deposit with the lessor as security against any future claims and recorded as part of restricted cash - long-term in the Partnership’s consolidated balance sheets. The UK taxing authority (or HMRC ) has been challenging the use of similar lease structures in the UK courts. One of those challenges was eventually decided in favor of HMRC (Lloyds Bank Equipment Leasing No. 1 or LEL1 ), with the lessor and lessee choosing not to appeal further. The LEL1 tax case concluded that capital allowances were not available to the lessor. On the basis of this conclusion, HMRC is now asking lessees on other leases, including the Teekay Nakilat Joint Venture, to accept that capital allowances are not available to their lessor. The Teekay Nakilat Joint Venture does not accept this contention and has informed HMRC of this position. It is not known at this time whether the Teekay Nakilat Joint Venture would eventually prevail in court. If the former lessor of the RasGas II LNG Carriers were to lose on a similar claim from HMRC, the Partnership’s 70% share of Teekay Nakilat Joint Venture's potential exposure is estimated to be approximately $60 million . Such estimate is primarily based on information received from the lessor. d) In May 2016, the Teekay LNG-Marubeni Joint Venture reached a settlement agreement with a charterer relating to a disputed charter contract termination for one of its LNG carriers that occurred in 2015. The charterer paid $39.0 million to the Teekay LNG-Marubeni Joint Venture in June 2016 for lost revenues, of which the Partnership’s share of $20.3 million was recorded in equity income for the year ended December 31, 2016 .

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information a) The changes in operating assets and liabilities for years ended December 31, 2016 , 2015 and 2014 are as follows: Year Ended Year Ended Year Ended Accounts receivable 5,494 (5,140 ) 9,957 Prepaid expenses 745 (494 ) 1,781 Accounts payable 2,791 2,127 (1,098 ) Accrued liabilities (1,572 ) (1,581 ) (6,759 ) Unearned revenue and long-term unearned revenue (3,218 ) (562 ) (536 ) Restricted cash (10,808 ) (2,785 ) — Advances to and from affiliates (9,699 ) (23,714 ) 17,953 Other operating assets and liabilities (4,402 ) (2,038 ) (2,476 ) Total (20,669 ) (34,187 ) 18,822 b) Cash interest paid (including realized losses on interest rate swaps) on long-term debt, advances from affiliates and capital lease obligations, net of amounts capitalized, during the years ended December 31, 2016 , 2015 and 2014 totaled $100.9 million , $94.5 million , and $128.7 million , respectively. c) During the years ended December 31, 2016 , 2015 and 2014 , cash paid for corporate income taxes was $4.9 million , $7.8 million and $2.3 million , respectively. d) During 2014, the sales of the Huelva Spirit and Algeciras Spirit conventional tankers resulted in the vessels under capital lease being returned to the owner and the capital lease obligations concurrently extinguished. Therefore, the sales of the Algeciras Spirit and Huelva Spirit under capital lease obligations of $56.2 million in 2014 and the concurrent extinguishment of the corresponding capital lease obligation of $56.2 million in 2014 were treated as non-cash transactions in the Partnership’s consolidated statements of cash flows. e) During 2014, the Partnership acquired an LPG carrier, the Norgas Napa , from Skaugen for $27.0 million , of which $21.6 million was paid in cash upon delivery and the remaining $5.4 million is an interest-bearing loan to Skaugen. f) A portion of the dividends declared by the Teekay Tangguh Joint Venture on February 1, 2014 that was used to settle advances made by the Teekay Tangguh Joint Venture to BLT LNG Tangguh Corporation and P.T. Berlian Laju Tanker of $14.4 million , was treated as a non-cash transaction in the Partnership’s consolidated statements of cash flows. g) As described in Notes 6a iii – Equity Accounted Investments, during 2014, the Partnership acquired the ownership interest of BG (which was subsequently acquired by Shell) in the BG Joint Venture. As compensation, the Partnership assumed Shell’s obligation (net of an agreement by Shell to pay the Partnership approximately $20.3 million ) to provide shipbuilding supervision and crew training services for the four LNG carrier newbuildings up to their delivery dates pursuant to a ship construction support agreement. The estimated fair value of the assumed obligation of approximately $33.3 million was used to offset the purchase price and the Partnership’s receivable from Shell and was treated as a non-cash transaction in the Partnership’s consolidated statements of cash flows.

Total Capital and Net Income Pe

Total Capital and Net Income Per Common Unit	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Total Capital and Net Income Per Common Unit	Total Capital and Net Income Per Common Unit As at December 31, 2016 , a total of 68.3% of the Partnership's common units outstanding were held by the public. The remaining common units, as well as the 2% general partner interest, were held by a subsidiary of Teekay Corporation. All of the Partnership's outstanding 9.00% Series A Cumulative Redeemable Perpetual Preferred Units (or the Series A Preferred Units ) are held by the public. Limited Partners’ Rights Significant rights of the Partnership’s limited partners include the following: • Right to receive distribution of Available Cash (as defined in the partnership agreement and which takes into account cash reserves for, among other things, future capital expenditures and future credit needs of the Partnership) 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 is responsible for the conduct, directions and management of the Partnership’s 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 our General Partner and its affiliates. Incentive Distribution Rights The General Partner is entitled to incentive distributions if the amount the Partnership distributes to common 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 $0.4125 98 % 2 % Up to $0.4625 98 % 2 % Above $0.4625 up to $0.5375 85 % 15 % Above $0.5375 up to $0.6500 75 % 25 % Above $0.6500 50 % 50 % During 2016 , the quarterly cash distributions were below $0.4625 per common unit and, consequently, the assumed distribution of net income was based on the limited partners' and General Partner’s ownership percentage for the purposes of the net income per common unit calculation. During 2015 and 2014 , quarterly cash distributions exceeded $0.4625 per common 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 common unit calculation. For more information on the increasing percentages to calculate the General Partner’s interest in net income, please refer to the Partnership’s Annual Report on Form 20-F for the year ended December 31, 2016. In the event of a liquidation, all property and cash in excess of that required to discharge all liabilities and liquidation amounts on the Series A Preferred Units will be distributed to the common unitholders and the 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 Per Common Unit Limited partners' interest in net income per common unit is determined by dividing net income, after deducting the amount of net income attributable to the non-controlling interests, the General Partner’s interest and the distributions on the Series A Preferred Units by the weighted-average number of common units outstanding during the period. The distributions payable on the Series A Preferred Units (which were issued on October 5, 2016) for the year ended December 31, 2016 were $2.7 million ( December 31, 2015 and 2014 – nil ). The General Partner’s and common unitholders’ interests 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 after establishment of cash reserves determined by the Partnership’s board of directors to provide for the proper conduct of the Partnership’s business, including reserves for maintenance and replacement capital expenditure and anticipated credit needs. In addition, the General Partner is entitled to incentive distributions if the amount the Partnership distributes to common unitholders with respect to any quarter exceeds specified target levels. Unlike available cash, net income is affected by non-cash items, such as depreciation and amortization, unrealized gains or losses on non-designated derivative instruments and foreign currency translation gains (losses). Pursuant to the Partnership agreement, allocations to partners are made on a quarterly basis. Equity Offerings The following table summarizes the issuances of common and preferred units over the three years ending December 31, 2016 : Date Units Type of Units Offering Gross Proceeds (i) $ Net Proceeds $ Teekay Corporation’s Ownership After the Offering (ii) Use of Proceeds July 2014 Public Offering 3,090,000 Common $ 44.65 140,784 140,484 33.96 % Prepayment of revolving credit facilities, funding of the Yamal LNG Project and funding newbuilding installments Continuous offering program during 2014 1,050,463 Common (iii) 42,556 41,655 (iii) General partnership purposes including funding newbuilding installments Continuous offering program during 2015 (iv) 1,173,428 Common (iii) 36,274 35,374 (iii) General partnership purposes, including funding newbuilding installments October 2016 Public Offering (v) 5,000,000 Preferred $ 25.00 125,000 120,707 (v) General partnership purposes, including debt repayments and funding newbuilding installments (i) Including the General Partner’s 2% proportionate capital contribution. (ii) Including Teekay Corporation’s indirect 2% general partner interest relating to common unit offerings. (iii) Commencing in May 2013, the Partnership implemented a continuous offering program (or COP ) under which the Partnership may issue new common units, representing limited partner interests, from time to time at market prices up to a maximum aggregate amount of $100 million . (iv) Includes 160,000 common units sold under the COP in December 2014 for which net proceeds of $6.8 million (including the General Partner’s 2% proportionate capital contribution) were received in January 2015. (v) On October 5, 2016, the Partnership issued Series A Preferred Units at a rate of 9.0% per annum of the stated liquidation preference of $25.00 per unit. At any time on or after October 5, 2021, the Partnership may redeem the Series A Preferred Units, in whole or in part, at a redemption price of $25.00 per unit plus all accumulated and unpaid distributions to the date of redemption, whether or not declared.

Unit-Based Compensation

Unit-Based Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Unit-Based Compensation	Unit-Based Compensation In March 2016, a total of 32,723 common units, with an aggregate value of $0.4 million , were granted to the non-management directors of the General Partner as part of their annual compensation for 2016. These common units were fully vested upon grant. During 2015 and 2014, the Partnership awarded 10,447 and 9,521 common units, respectively, as compensation to non-management directors. The awards were fully vested in March 2015 and March 2014, respectively. The compensation to the non-management directors is included in general and administrative expenses on the Partnership’s consolidated statements of income. The Partnership grants restricted unit awards as incentive-based compensation under the Teekay LNG Partners L.P. 2005 Long-Term Incentive Plan to certain of the Partnership’s employees and to certain employees of Teekay Corporation’s subsidiaries that provide services to the Partnership. The Partnership measures the cost of such awards using the grant date fair value of the award and recognizes that cost, net of estimated forfeitures, over the requisite service period. The requisite service period consists of the period from the grant date of the award to the earlier of the date of vesting or the date the recipient becomes eligible for retirement. For unit-based compensation awards subject to graded vesting, the Partnership calculates the value for the award as if it was one single award with one expected life and amortizes the calculated expense for the entire award on a straight-line basis over the requisite service period. The compensation cost of the Partnership’s unit-based compensation awards are reflected in general and administrative expenses in the Partnership’s consolidated statements of income. During March 2016, 2015 and 2014, the Partnership granted 132,582 , 32,054 and 31,961 restricted units, respectively, with grant date fair values of $1.5 million , $1.1 million and $1.3 million , respectively, to certain of the Partnership’s employees and to certain employees of Teekay Corporation’s subsidiaries who provide services to the Partnership, based on the Partnership’s closing common unit price on the grant date. Each restricted unit is equal in value to one of the Partnership's common units plus reinvested distributions from the grant date to the vesting date. The restricted units vest equally over three years from the grant date. Any portion of a restricted unit award that is not vested on the date of a recipient’s termination of service is canceled, unless their termination arises as a result of the recipient’s retirement, and in this case, the restricted unit award will continue to vest in accordance with the vesting schedule. Upon vesting, the value of the restricted unit awards is paid to each recipient in the form of common units, net of withholding tax. During the years ended December 31, 2016 , 2015 and 2014 , the Partnership recorded an expense of $1.3 million , $1.2 million , and $1.0 million , respectively, related to the restricted units.

Restructuring Charges

Restructuring Charges	12 Months Ended
	Dec. 31, 2016
Restructuring and Related Activities [Abstract]
Restructuring Charges	Restructuring Charges a) Compania Espanole de Petroles, S.A., the charterer and owner of the Partnership’s former conventional vessels under capital lease, sold the Tenerife Spirit , Algeciras Spirit , and Huelva Spirit between December 2013 and August 2014. On redeliveries of the vessels, the charter contract with the Partnership was terminated. As a result of these sales, the Partnership recorded restructuring charges of nil , nil and $2.0 million for the years ended December 31, 2016 , 2015 and 2014 , respectively. The balances outstanding of $0.7 million as at December 31, 2016 and 2015 , respectively, are included in accrued liabilities in the Partnership’s consolidated balance sheets. b) During 2015, pursuant to a request by the charterer of the Alexander Spirit , the Partnership changed the crew on the vessel which resulted in a restructuring charge of $4.0 million relating to seafarer severance payments. The full amount of the restructuring charge was recovered from the charterer and the recovery was included in voyage revenues in the Partnership’s consolidated statements of income. The balances outstanding of nil and $1.1 million as at December 31, 2016 and 2015 , respectively, are included in accrued liabilities in the Partnership's consolidated balance sheets.

Write-Down and Loss on Sale of

Write-Down and Loss on Sale of Vessels Write-Down and Loss on Sale of Vessels	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Write-Down and Loss on Sale of Vessels	Write-Down and Loss on Sale of Vessels a) During February and March 2016, Centrofin Management Inc. (or Centrofin ), the charterer for both the Bermuda Spirit and Hamilton Spirit Suezmax tankers, exercised its option under the charter contracts to purchase both vessels. As a result of Centrofin’s acquisition of the vessels, the Partnership recorded a $27.4 million loss on the sale of the vessels and associated charter contracts in the first quarter of 2016. The Bermuda Spirit was sold on April 15, 2016 and the Hamilton Spirit was sold on May 17, 2016. The Partnership used the total proceeds of $94.3 million from the sales primarily to repay existing term loans associated with these vessels. b) On November 30, 2016, the Partnership reached an agreement to sell the Asian Spirit Suezmax tanker for net proceeds of $20.6 million and as a result, recorded an $11.5 million impairment on the write-down of the vessel. Delivery of the vessel to the new owner occurred on March 21, 2017. The Partnership used the net proceeds from the sales primarily to repay existing term loans associated with the vessel. As at December 31, 2016 , the vessel was classified as held for sale in the Partnership’s consolidated balance sheets.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events a) In December 2016, the Partnership entered into an agreement to acquire Skaugen's 35% ownership interest in Skaugen Gulf Petchem Carriers B.S.C.(c) (or the Skaugen LPG Joint Venture ) which owns the LPG carrier Norgas Sonoma . The Partnership entered into this transaction in exchange for a portion of past due amounts owed to the Partnership by Skaugen. The Skaugen LPG Joint Venture’s other shareholders include Nogaholding, which has a 35% ownership interest and Suffun Bahrain W.L.L.,which has a 30% ownership interest. Both Nogaholding and Suffun exercised their respective option to participate in the sale of the Norgas Sonoma and as a result, on April 20, 2017, the Partnership acquired 100% ownership interest in the Norgas Sonoma for $13 million . b) On January 23, 2017, the Partnership issued in the Norwegian bond market NOK 300 million (equivalent to approximately $36 million ) in new senior unsecured bonds through an add-on to its existing NOK bonds due in October 2021, priced at 103.75% of face value. All principal and interest payments have been economically swapped into U.S. Dollars with a fixed interest rate of 7.69% . c) On February 28, 2017, the Partnership took delivery of its third MEGI LNG carrier newbuilding, the Torben Spirit , which commenced its 10 -month plus one -year option charter contract with a major energy company on March 3, 2017. The Partnership received proceeds through a sale-leaseback transaction of approximately $125 million in March 2017 for this MEGI LNG carrier newbuilding. d) On December 21, 2016, the RasGas 3 Joint Venture, of which the Partnership has a 40% ownership interest, completed its debt refinancing by entering into a $723 million secured term loan facility maturing in 2026 which replaced its outstanding term loan of $610 million . As a result, the RasGas 3 Joint Venture distributed $100 million in February 2017 to its shareholders, of which the Partnership's proportionate share was $40 million . e) On March 31, 2017, the Teekay LNG-Marubeni Joint Venture completed the refinancing of its existing $396 million debt facility by entering into a new $335 million U.S. Dollar-denominated term loan maturing in September 2019. As part of the completed refinancing, the Partnership invested $57 million of additional equity, based on its proportionate ownership interest, into the Teekay LNG-Marubeni Joint Venture. f) On April 21, 2017, the Partnership entered into a 10 -year $174 million sale-leaseback agreement with China Construction Bank Financial Leasing Co. Ltd. (or CCBL ) for one of our nine wholly-owned LNG carrier newbuildings scheduled to deliver in late-2017, and at such date, CCBL will take delivery and charter the vessel back to the Partnership. At the end of the 10 -year tenor of this lease, the Partnership has an obligation to repurchase the vessel from CCBL.

Summary of Significant Accoun29

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The 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 LNG Partners L.P. (or the Partnership ), which is a limited partnership organized under the laws of the Republic of The Marshall Islands and its wholly owned or controlled subsidiaries. The preparation of consolidated 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 may differ from those estimates. Significant intercompany balances and transactions have been eliminated upon consolidation. In addition, certain of the comparative figures have been reclassified to conform to the presentation adopted in the current period relating to certain operating activities in the Partnership's consolidated statements of cash flows and certain of the summarized financial information in Note 6c.
Foreign currency	Foreign currency The consolidated financial statements are stated in U.S. Dollars and the functional currency of the Partnership and its subsidiaries is the U.S. Dollar. Transactions involving other currencies during the year are converted into U.S. Dollars using the exchange rates in effect at the time of the transactions. At the balance sheet date, monetary assets and liabilities that are denominated in currencies other than the U.S. Dollar are translated to reflect the year-end exchange rates. Resulting gains or losses are reflected separately in the accompanying consolidated statements of income.
Operating revenues and expenses	Operating revenues and expenses The lease element of time-charters and bareboat charters accounted for as operating leases are recognized by the Partnership on a straight-line basis daily over the term of the charter as the applicable vessel operates under the charter. The lease element of the Partnership’s time-charters that are accounted for as direct financing leases are reflected on the balance sheets as net investments in direct financing leases. The lease element is recognized over the lease term using the effective interest rate method and is included in voyage revenues. The Partnership recognizes revenues from the non-lease element of time-charter contracts as services are performed. The Partnership does not recognize revenues during days that the vessel is off-hire. Voyage expenses are all expenses unique to a particular voyage, including bunker fuel expenses, port fees, cargo loading and unloading expenses, canal tolls, agency fees and commissions. Vessel operating expenses include crewing, ship management services, repairs and maintenance, insurance, stores, lube oils and communication expenses. Voyage expenses and vessel operating expenses are recognized when incurred.
Cash and cash equivalents	Cash and cash equivalents The Partnership classifies all highly-liquid investments with a maturity date of three months or less when purchased as cash and cash equivalents.
Accounts receivable and allowance for doubtful accounts	Accounts receivable and allowance for doubtful accounts Accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts is the Partnership’s best estimate of the amount of probable credit losses in existing accounts receivable. The Partnership determines the allowance based on historical write-off experience and customer economic data. The Partnership reviews the allowance for doubtful accounts regularly and past due balances are reviewed for collectability. Account balances are charged against the allowance when the Partnership believes that the receivable will not be recovered.
Vessels and equipment	Vessels and equipment All pre-delivery costs incurred during the construction of newbuildings, including interest and supervision and technical costs, are capitalized. The acquisition cost and all costs incurred to restore used vessels purchased by the Partnership to the standards required to properly service the Partnership’s customers are capitalized. Depreciation is calculated on a straight-line basis over a vessel’s estimated useful life, less an estimated residual value. Depreciation is calculated using an estimated useful life of 25 years for conventional tankers, 30 years for liquefied petroleum gas (or LPG ) carriers and 35 years for liquefied natural gas (or LNG ) carriers, from the date the vessel is delivered from the shipyard, or a shorter period if regulations prevent the Partnership from operating the vessels for 25 years , 30 years , or 35 years , respectively. Depreciation of vessels and equipment for the years ended December 31, 2016 , 2015 and 2014 aggregated $86.6 million , $83.4 million and $70.1 million , respectively. Depreciation and amortization includes depreciation on all owned vessels and amortization of vessels accounted for as capital leases. Vessel capital modifications include the addition of new equipment or can encompass various modifications to the vessel which are aimed at improving or increasing the operational efficiency and functionality of the asset. This type of expenditure is amortized over the estimated useful life of the modification. Expenditures covering recurring routine repairs and maintenance are expensed as incurred. Interest costs capitalized to vessels and equipment for the years ended December 31, 2016 , 2015 and 2014 aggregated $9.9 million , $8.2 million and $3.1 million , respectively. Generally, the Partnership dry docks each of its vessels every five years. In addition, a shipping society classification intermediate survey is performed on the Partnership’s LNG and LPG carriers between the second and third year of the five -year dry-docking cycle. The Partnership capitalizes certain costs incurred during dry docking and for the survey and amortizes those costs on a straight-line basis from the completion of a dry docking or intermediate survey over the estimated useful life of the dry dock. The Partnership includes in capitalized dry docking those costs incurred as part of the dry docking to meet regulatory requirements, or expenditures that either add economic life to the vessel, increase the vessel’s earning capacity or improve the vessel’s operating efficiency. The Partnership expenses costs related to routine repairs and maintenance performed during dry docking that do not improve operating efficiency or extend the useful lives of the assets. The following table summarizes the change in the Partnership’s capitalized dry docking costs, from January 1, 2014 to December 31, 2016 : Year Ended December 31, 2016 2015 2014 Balance at January 1, 33,916 33,635 40,328 Cost incurred for dry docking 13,944 10,357 13,471 Sales of vessels (2,886 ) — (5,327 ) Dry-dock amortization (11,436 ) (10,076 ) (14,837 ) Balance at December 31, 33,538 33,916 33,635 Vessels and equipment that are “held and used” are assessed for impairment when events or circumstances indicate the carrying amount of the asset may not be recoverable. If the asset’s net carrying value exceeds the net undiscounted cash flows expected to be generated over its remaining useful life, the carrying amount of the asset is reduced to its estimated fair value. The estimated fair value for the Partnership’s impaired vessels is determined using discounted cash flows or appraised values. In cases where an active second hand sale and purchase market does not exist, the Partnership uses a discounted cash flow approach to estimate the fair value of an impaired vessel. In cases where an active second hand sale and purchase market exists, an appraised value is generally the amount the Partnership would expect to receive if it were to sell the vessel. Such appraisal is normally completed by the Partnership. Vessels and equipment that are held for sale are measured at the lower of their carrying amount or fair value less costs to sell and are not depreciated while classified as held for sale. Interest and other expenses attributable to vessels and equipment classified as held for sale, or to their related liabilities, continue to be recognized as incurred. Gains on vessels sold and leased back under capital leases are deferred and amortized over the remaining term of the capital lease. Losses on vessels sold and leased back under capital leases are recognized immediately when the fair value of the vessel at the time of sale and lease-back is less than its book value. In such case, the Partnership would recognize a loss in the amount by which book value exceeds fair value.
Investments in and advances to equity accounted joint ventures	Investments in and advances to equity accounted joint ventures The Partnership’s investments in certain joint ventures are accounted for using the equity method of accounting. Under the equity method of accounting, investments are stated at initial cost and are adjusted for subsequent additional investments and the Partnership’s proportionate share of earnings or losses and distributions. In addition, the Partnership’s advances to equity accounted joint ventures are recorded at cost. The Partnership evaluates its investment in and advances to equity accounted joint ventures for impairment when events or circumstances indicate that the carrying value of such investments may have experienced an other-than-temporary decline in value below its carrying value. If the estimated fair value is less than the carrying value, the carrying value is written down to its estimated fair value and the resulting impairment is recorded in the Partnership’s consolidated statements of income.
Debt issuance costs	Debt issuance costs Debt issuance costs, including fees, commissions and legal expenses, are presented as a direct reduction from the carrying amount of the debt liability with the exception if debt issuance costs are not attributable to a specific debt liability or the debt issuance costs exceed the carrying value of the related debt liability, the debt issuance costs are deferred and presented as other assets in the Partnership's consolidated balance sheets. Debt issuance costs are amortized on an effective interest rate method over the term of the relevant loan. Amortization of debt issuance costs is included in interest expense.
Goodwill and intangible assets	Goodwill and intangible assets Goodwill is not amortized, but reviewed for impairment at the reporting unit level on an annual basis or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. When goodwill is reviewed for impairment, the Partnership may elect to assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, including goodwill. Alternatively, the Partnership may bypass this step and use a fair value approach to identify potential goodwill impairment and, when necessary, measure the amount of impairment. The Partnership uses a discounted cash flow model to determine the fair value of reporting units, unless there is a readily determinable fair market value. Intangible assets are assessed for impairment when and if impairment indicators exist. An impairment loss is recognized if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. The Partnership’s finite life intangible assets consist of acquired time-charter contracts and are amortized on a straight-line basis over the remaining term of the time-charters. Finite life intangible assets are assessed for impairment when events or circumstances indicate that the carrying value may not be recoverable.
Derivative instruments	Derivative instruments All derivative instruments are initially recorded at fair value as either assets or liabilities in the accompanying consolidated balance sheet and subsequently remeasured to fair value, regardless of the purpose or intent for holding the derivative. The method of recognizing the resulting gain or loss is dependent on whether the derivative contract is designed to hedge a specific risk and whether the contract qualifies for hedge accounting. When a derivative is designated as a cash flow hedge, the Partnership formally documents the relationship between the derivative and the hedged item. This documentation includes the strategy and risk management objective for undertaking the hedge and the method that will be used to assess the effectiveness of the hedge. Any hedge ineffectiveness is recognized immediately in earnings, as are any gains and losses on the derivative that are excluded from the assessment of hedge effectiveness. The Partnership does not apply hedge accounting if it is determined that the hedge was not effective or will no longer be effective, the derivative was sold or exercised, or the hedged item was sold, repaid or no longer possible of occurring. For derivative financial instruments designated and qualifying as cash flow hedges, changes in the fair value of the effective portion of the derivative financial instruments are initially recorded as a component of accumulated other comprehensive income (loss) in total equity. In the periods when the hedged items affect earnings, the associated fair value changes on the hedging derivatives are transferred from total equity to the corresponding earnings line item in the consolidated statements of income. The ineffective portion of the change in fair value of the derivative financial instruments is immediately recognized in earnings in the consolidated statements of income. If a cash flow hedge is terminated and the originally hedged item is still considered possible of occurring, the gains and losses initially recognized in total equity remain there until the hedged item impacts earnings, at which point they are transferred to the corresponding earnings line item (e.g. interest expense) in the consolidated statements of income. If the hedged items are no longer possible of occurring, amounts recognized in total equity are immediately transferred to the earnings item in the consolidated statements of income. For derivative financial instruments that are not designated or that do not qualify as hedges under Financial Accounting Standards Board (or FASB ) Accounting Standards Codification (or ASC ) 815, Derivatives and Hedging , the changes in the fair value of the derivative financial instruments are recognized in earnings. Gains and losses from the Partnership’s non-designated interest rate swaps, interest rate swaptions, and the Partnership’s agreement with Teekay Corporation for the Suezmax tanker the Toledo Spirit (see Note 11c) are recorded in realized and unrealized loss on non-designated derivative instruments in the Partnership’s consolidated statements of income. Gains and losses from the Partnership’s cross currency swaps are recorded in foreign exchange gain in the Partnership’s consolidated statements of income.
Unit-based compensation	Unit-based compensation The Partnership grants restricted unit awards as incentive-based compensation under the Teekay LNG Partners L.P. 2005 Long-Term Incentive Plan to certain of the Partnership’s employees and to certain employees of Teekay Corporation’s subsidiaries that provide services to the Partnership and its subsidiaries. The Partnership measures the cost of such awards using the grant date fair value of the award and recognizes that cost, net of estimated forfeitures, over the requisite service period. The requisite service period consists of the period from the grant date of the award to the earlier of the date of vesting or the date the recipient becomes eligible for retirement. For unit-based compensation awards subject to graded vesting, the Partnership calculates the value for the award as if it was one single award with one expected life and amortizes the calculated expense for the entire award on a straight-line basis over the requisite service period. The compensation cost of the Partnership’s unit-based compensation awards are reflected in general and administrative expenses in the Partnership’s consolidated statements of income.
Income taxes	Income taxes The Partnership accounts for income taxes using the liability method. All but two of the Partnership’s Spanish-flagged vessels are subject to the Spanish Tonnage Tax Regime (or TTR ). Under this regime, the applicable tax is based on the weight (measured as net tonnage) of the vessel and the number of days during the taxable period that the vessel is at the Partnership’s disposal, excluding time required for repairs. The income the Partnership receives with respect to the remaining two Spanish-flagged vessels is taxed in Spain at a rate of 25% . However, these two vessels are registered in the Canary Islands Special Ship Registry. Consequently, the Partnership is allowed a credit, equal to 90% of the tax payable on income from the commercial operation of these vessels, against the tax otherwise payable. This effectively results in an income tax rate of approximately 2.5% on income from the operation of these two Spanish-flagged vessels. The Partnership recognizes the benefits of uncertain tax positions when it is more-likely-than-not that a tax position taken or expected to be taken in a tax return will be sustained upon examination, including resolution of any related appeals or litigation processes, based on the technical merits of the position. If a tax position meets the more-likely-than-not recognition threshold, it is measured to determine the amount of benefit to recognize in the financial statements. The Partnership recognizes interest and penalties related to uncertain tax positions in income tax expense in the Partnership’s consolidated statements of income.
Guarantees	Guarantees Guarantees issued by the Partnership, excluding those that are guaranteeing its own performance, are recognized at fair value at the time the guarantees are issued and are presented in the Partnership’s consolidated balance sheets as other long-term liabilities. The liability recognized on issuance is amortized to other income on the Partnership’s consolidated statements of income over the term of the guarantee. If it becomes probable that the Partnership will have to perform under a guarantee, the Partnership will recognize an additional liability if the amount of the loss can be reasonably estimated.
Accumulated other comprehensive (loss) income	Accumulated other comprehensive income (loss) The following table contains the changes in the balance of the Partnership’s only component of accumulated other comprehensive income (loss) for the periods presented: Qualifying Cash Balance as at December 31, 2013 131 Other comprehensive loss (1,534 ) Balance as at December 31, 2014 (1,403 ) Other comprehensive loss (648 ) Balance as at December 31, 2015 (2,051 ) Other comprehensive income 2,626 Balance as at December 31, 2016 575
Accounting Pronouncements	In May 2014, the FASB issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers , (or ASU 2014-09 ). ASU 2014-09 will require an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This update creates a five-step model that requires entities to exercise judgment when considering the terms of the contract(s) which include (i) identifying the contract(s) with the customer, (ii) identifying the separate performance obligations in the contract, (iii) determining the transaction price, (iv) allocating the transaction price to the separate performance obligations, and (v) recognizing revenue as each performance obligation is satisfied. ASU 2014-09 is effective for the Partnership on January 1, 2018 and shall be applied, at the Partnership’s option, retrospectively to each period presented or as a cumulative-effect adjustment as of the date of adoption. The Partnership’s only significant source of revenue that will be accounted for pursuant to ASU 2014-09 is its non-lease portion of time-charter contracts. Based on the Partnership’s preliminary assessment of ASU 2014-09, when applied to the standard terms of the Partnership’s time-charter contracts, no significant impact on the accounting for the non-lease portion of time-charter contracts is expected. The Partnership is in the process of validating aspects of its preliminary assessment of ASU 2014-09, determining the transitional impact and completing other items required for the adoption of ASU 2014-09. In February 2016, the FASB issued Accounting Standards Update 2016-02, Leases (or ASU 2016-02 ). ASU 2016-02 establishes a right-of-use model that requires a lessee to record a right of use asset and a lease liability on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The Partnership expects to adopt ASU 2016-02 on January 1, 2018. A modified retrospective transition approach is required for lessees for capital and operating leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements, with certain practical expedients available. The Partnership’s lessee-related leasing activities primarily consist of on-balance sheet finance leases. The accounting for such transactions is not significantly impacted by ASU 2016-02. The Partnership also has extensive lessor-related leasing activities, which consist of bareboat charter contracts and the lease portion of time-charter contracts. However, ASU 2016-02 does not make extensive changes to lessor accounting. Based on the Partnership’s preliminary assessment of ASU 2016-02 no significant impact on the accounting for its lessor-related leasing activities is expected. The Partnership is in the process of validating aspects of its preliminary assessment of ASU 2016-02, determining the transitional impact and completing other items required for the adoption of ASU 2016-02. In June 2016, the FASB issued Accounting Standards Update 2016-13, Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Instruments . This update replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. This update is effective for the Partnership January 1, 2020, with a modified-retrospective approach. The Partnership is currently evaluating the effect of adopting this new guidance. In August 2016, the FASB issued Accounting Standards Update 2016-15, Statement of Cash Flows: Classification of Certain Cash Receipts and Cash Payments , which, among other things, provides guidance on two acceptable approaches of classifying distributions received from equity method investees in the statement of cash flows. This update is effective for the Partnership January 1, 2018, with a retrospective approach. The Partnership is currently evaluating the effect of adopting this new guidance.

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Changes in Partnership's Capitalized Dry Docking Costs	The following table summarizes the change in the Partnership’s capitalized dry docking costs, from January 1, 2014 to December 31, 2016 : Year Ended December 31, 2016 2015 2014 Balance at January 1, 33,916 33,635 40,328 Cost incurred for dry docking 13,944 10,357 13,471 Sales of vessels (2,886 ) — (5,327 ) Dry-dock amortization (11,436 ) (10,076 ) (14,837 ) Balance at December 31, 33,538 33,916 33,635
Changes in Balances of Component of Accumulated Other Comprehensive (Loss) Income	The following table contains the changes in the balance of the Partnership’s only component of accumulated other comprehensive income (loss) for the periods presented: Qualifying Cash Balance as at December 31, 2013 131 Other comprehensive loss (1,534 ) Balance as at December 31, 2014 (1,403 ) Other comprehensive loss (648 ) Balance as at December 31, 2015 (2,051 ) Other comprehensive income 2,626 Balance as at December 31, 2016 575

Financial Instruments (Tables)

Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Schedule of Estimated Fair Value of Partnership's Financial Instruments on Recurring Basis	The following table includes the estimated fair value and carrying value of those assets and liabilities that are measured at fair value on a recurring and non-recurring basis, as well as the estimated fair value of the Partnership’s financial instruments that are not accounted for at a fair value on a recurring basis. December 31, 2016 December 31, 2015 Fair Value Carrying Fair Carrying Fair Recurring: Cash and cash equivalents and restricted cash Level 1 243,173 243,173 214,000 214,000 Derivative instruments (note 12) Interest rate swap agreements – assets Level 2 1,080 1,080 — — Interest rate swap agreements – liabilities Level 2 (87,681 ) (87,681 ) (104,137 ) (104,137 ) Interest rate swaption agreements – assets Level 2 3,283 3,283 5,623 5,623 Interest rate swaption agreements – liabilities Level 2 (4,230 ) (4,230 ) (6,406 ) (6,406 ) Cross-currency swap agreements Level 2 (99,786 ) (99,786 ) (128,782 ) (128,782 ) Other derivative Level 3 2,134 2,134 (6,296 ) (6,296 ) Non-recurring: Vessel held for sale Level 2 20,580 20,580 — — Other: Advances to equity accounted joint ventures (note 6) (i) 272,514 (i) 159,870 (i) Long-term receivable included in accounts receivable and other assets (ii) Level 3 10,985 10,944 16,453 16,427 Long-term debt – public (note 9) Level 1 (368,612 ) (366,418 ) (291,247 ) (288,333 ) Long-term debt – non-public (note 9) Level 2 (1,422,614 ) (1,381,287 ) (1,707,962 ) (1,677,139 ) (i) The advances to equity accounted joint ventures together with the Partnership’s equity investments in the joint ventures form the net aggregate carrying value of the Partnership’s interests in the joint ventures in these consolidated financial statements. The fair values of the individual components of such aggregate interests are not determinable. (ii) As at December 31, 2016 , the estimated fair value of the non-interest bearing receivable is based on the remaining future fixed payments of $10.9 million to be received from Royal Dutch Shell Plc (or Shell ) (formerly BG International Limited (or BG )), as part of the ship construction support agreement, as well as an estimated discount rate of 8.0% . As there is no market rate for the equivalent of an unsecured non-interest bearing receivable from Shell, the discount rate is based on unsecured debt instruments of similar maturity held, adjusted for a liquidity premium. A higher or lower discount rate would result in a lower or higher fair value asset.
Changes in Fair Value of Assets Measured on Recurring Basis Using Significant Unobservable Inputs (Level 3)	Changes in fair value during the years ended December 31, 2016 and 2015 for the Partnership’s other derivative asset, the Toledo Spirit time-charter derivative, which is described below and is measured at fair value on a recurring basis using significant unobservable inputs (Level 3), are as follows: Year Ended December 31, 2016 2015 Fair value at beginning of year (6,296 ) (2,137 ) Realized and unrealized gains (losses) included in earnings 3,316 (5,039 ) Settlements 5,114 880 Fair value at end of year 2,134 (6,296 )
Summary of Partnership's Loan Receivables and Other Financing Receivables	The following table contains a summary of the Partnership’s loan receivables and other financing receivables by type of borrower and the method by which the Partnership monitors the credit quality of its financing receivables on a quarterly basis. Class of Financing Receivable Credit Quality Indicator Grade December 31 December 31 Direct financing leases Payment activity Performing 643,008 666,658 Other receivables: Long-term receivable and accrued revenue included in accounts receivable and other assets Payment activity Performing 12,171 28,256 Advances to equity accounted joint ventures Other internal metrics Performing 272,514 159,870 927,693 854,784

Segment Reporting (Tables)

Segment Reporting (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Revenues and Percentage of Consolidated Voyage Revenues from Top Customers	The following table presents voyage revenues and percentage of consolidated voyage revenues for the Partnership’s customers who accounted for 10% or more of the Partnership's consolidated voyage revenues during any of the periods presented. (U.S. Dollars in millions) Year Ended Year Ended Year Ended Ras Laffan Liquefied Natural Gas Company Ltd. (i) $70.3 or 18% $70.1 or 18% $69.8 or 17% Shell Spain LNG S.A.U. (i),(ii) $48.2 or 12% $48.5 or 12% $51.8 or 13% The Tangguh Production Sharing Contractors (i) $44.4 or 11% $44.9 or 11% $44.3 or 11% (i) Liquefied gas segment. (ii) Shell Spain LNG S.A.U. acquired the charter contracts from Repsol YPF, S.A. in March 2014. The voyage revenues in 2014 consisted of the voyage revenues from both customers relating to the same charter contract.
Segment Reporting Information	The following tables include results for these segments for the years presented in these financial statements. Year Ended December 31, 2016 Liquefied Gas Conventional Total Voyage revenues 336,530 59,914 396,444 Voyage expenses (449 ) (1,207 ) (1,656 ) Vessel operating expenses (66,087 ) (22,503 ) (88,590 ) Depreciation and amortization (80,084 ) (15,458 ) (95,542 ) General and administrative expenses (i) (15,310 ) (3,189 ) (18,499 ) Write-down and loss on sale of vessels — (38,976 ) (38,976 ) Income (loss) from vessel operations 174,600 (21,419 ) 153,181 Equity income 62,307 — 62,307 Investment in and advances to equity accounted joint ventures 1,037,726 — 1,037,726 Total assets at December 31, 2016 3,957,088 193,553 4,150,641 Expenditures for vessels and equipment (344,924 ) (63 ) (344,987 ) Expenditures for dry docking (13,944 ) — (13,944 ) Year Ended December 31, 2015 Liquefied Gas Conventional Total Voyage revenues 305,056 92,935 397,991 Voyage recoveries (expenses) 203 (1,349 ) (1,146 ) Vessel operating expenses (63,344 ) (30,757 ) (94,101 ) Depreciation and amortization (71,323 ) (20,930 ) (92,253 ) General and administrative expenses (i) (19,392 ) (5,726 ) (25,118 ) Restructuring charges — (4,001 ) (4,001 ) Income from vessel operations 151,200 30,172 181,372 Equity income 84,171 — 84,171 Investment in and advances to equity accounted joint ventures 883,731 — 883,731 Total assets at December 31, 2015 3,550,396 360,527 3,910,923 Expenditures for vessels and equipment (191,642 ) (327 ) (191,969 ) Expenditures for dry docking (8,659 ) (1,698 ) (10,357 ) Year Ended December 31, 2014 Liquefied Gas Conventional Total Voyage revenues 307,426 95,502 402,928 Voyage expenses (1,768 ) (1,553 ) (3,321 ) Vessel operating expenses (59,087 ) (36,721 ) (95,808 ) Depreciation and amortization (71,711 ) (22,416 ) (94,127 ) General and administrative expenses (i) (17,992 ) (5,868 ) (23,860 ) Restructuring charges — (1,989 ) (1,989 ) Income from vessel operations 156,868 26,955 183,823 Equity income 115,478 — 115,478 Expenditures for vessels and equipment (193,669 ) (586 ) (194,255 ) Expenditures for dry docking (8,127 ) (5,344 ) (13,471 ) (i) Includes direct general and administrative expenses and indirect general and administrative expenses (allocated to each segment based on estimated use of corporate resources).
Reconciliation of Total Segment Assets	A reconciliation of total segment assets presented in the consolidated balance sheets is as follows: December 31 December 31 Total assets of the liquefied gas segment 3,957,088 3,550,396 Total assets of the conventional tanker segment 193,553 360,527 Unallocated: Cash and cash equivalents 126,146 102,481 Accounts receivable and prepaid expenses 28,948 26,550 Advances to affiliates 9,739 13,026 Consolidated total assets 4,315,474 4,052,980

Leases and Restricted Cash (Tab

Leases and Restricted Cash (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Capital Lease Obligations	Capital Lease Obligations December 31 December 31 LNG Carriers 338,257 — Suezmax Tankers 54,582 59,127 Total obligations under capital lease 392,839 59,127 Less current portion (40,353 ) (4,546 ) Long-term obligations under capital lease 352,486 54,581
Commitment Under Capital Leases	As at December 31, 2016 , the remaining commitments under the two capital leases for Suezmax tankers, including the related purchase obligations, approximated $58.2 million , including imputed interest of $3.6 million , repayable from 2017 through 2018, as indicated below: Year Commitment 2017 $ 30,953 2018 $ 27,296 As at December 31, 2016 , the remaining commitments under the two capital leases for the Creole Spirit and the Oak Spirit , including the related purchase obligations, approximated $478.1 million , including imputed interest of $139.8 million , repayable from 2017 through 2026, as indicated below: Year Commitment 2017 $ 30,065 2018 $ 30,065 2019 $ 30,065 2020 $ 30,147 2021 $ 30,065 Thereafter $ 327,686
Estimated Future Minimum Rental Payments to be Received and Paid Under the Lease Contracts	As at December 31, 2016 , the total estimated future minimum rental payments to be received and paid under the lease contracts are as follows: Year Head Lease Receipts (i) Sublease Payments (i) (ii) 2017 $ 21,242 $ 24,113 2018 $ 21,242 $ 24,113 2019 $ 21,242 $ 24,113 2020 $ 21,242 $ 24,113 2021 $ 21,242 $ 24,113 Thereafter $ 154,095 $ 174,959 Total $ 260,305 $ 295,524 (i) The Head Leases are fixed-rate operating leases while the Subleases have a small variable-rate component. As at December 31, 2016 , the Partnership had received $250.0 million of aggregate Head Lease receipts and had paid $187.9 million of aggregate Sublease payments. The portion of the Head Lease receipts that have not been recognized into earnings are deferred and amortized on a straight line basis over the lease terms and, as at December 31, 2016 , $3.7 million (December 31, 2015 – $3.8 million ) and $36.7 million (December 31, 2015 – $40.4 million ) of Head Lease receipts had been deferred and included in unearned revenue and other long-term liabilities, respectively, in the Partnership’s consolidated balance sheets. (ii) The amount of payments under the Subleases are updated annually to reflect any changes in the lease payments due to changes in tax law.
Net Investments in Direct Financing Leases	The following table lists the components of the net investments in direct financing leases: December 31 December 31 Total minimum lease payments to be received 764,970 843,079 Estimated unguaranteed residual value of leased properties 194,965 194,965 Initial direct costs 393 425 Less unearned revenue (317,320 ) (371,811 ) Total net investments in direct financing leases 643,008 666,658 Less current portion (150,342 ) (20,606 ) Net investments in direct financing leases 492,666 646,052

Equity Accounted Investments (T

Equity Accounted Investments (Tables)	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Financial Information of Joint Ventures	A summary of the Partnership's investments in and advances to equity accounted investees are as follows: As at December 31, Name Ownership Percentage # of Delivered Vessels Newbuildings on order 2016 2015 Bahrain LNG Joint Venture (i) 30% - 1 63,933 — Yamal LNG Joint Venture (ii) 50% - 6 152,702 99,886 BG Joint Venture (iii) 20%-30% - 4 33,860 25,574 Exmar LPG Joint Venture (iv) 50% 19 4 167,763 166,430 Teekay LNG-Marubeni Joint Venture (v) 52% 6 - 299,601 294,433 Excalibur and Excelsior Joint Ventures (vi) 49%-50% 2 - 79,577 77,845 Angola Joint Venture (vii) 33% 4 - 65,644 58,170 RasGas 3 Joint Venture (viii) 40% 4 - 174,646 161,393 35 15 1,037,726 883,731 (i) Bahrain LNG Joint Venture On December 2, 2015, the Partnership ( 30% ) entered into a joint venture agreement with National Oil & Gas Authority (or Nogaholding ) ( 30% ), Gulf Investment Corporation (or GIC ) ( 24% ) and Samsung C&T (or Samsung ) ( 16% ) to form a joint venture, Bahrain LNG W.L.L. (or the Bahrain LNG Joint Venture ), for the development of an LNG receiving and regasification terminal in Bahrain. The project will include an offshore LNG receiving jetty and breakwater, an adjacent regasification platform, subsea gas pipelines from the platform to shore, an onshore gas receiving facility, and an onshore nitrogen production facility with a total LNG terminal capacity of 800 million standard cubic feet per day and will be owned and operated under a 20 -year agreement commencing in early-2019. In addition, the Partnership will supply a floating storage unit (or FSU ) in connection with this project, which will be modified from one of the Partnership’s nine MEGI LNG carrier newbuildings ordered from Daewoo Shipbuilding & Marine Engineering Co. (or DSME ) (see Note 13a), through a 20 -year time-charter contract with the Bahrain LNG Joint Venture. As at December 31, 2016 , the Partnership had advanced $62.9 million ( December 31, 2015 – $ nil ) to the Bahrain LNG Joint Venture. These advances bear interest at LIBOR plus 1.25% and as at December 31, 2016 , the interest accrued on these advances was $0.1 million ( December 31, 2015 – $ nil ). These amounts are included in the table above. (ii) Yamal LNG Joint Venture On July 9, 2014, the Partnership entered into a 50 /50 joint venture (or the Yamal LNG Joint Venture ) with China LNG Shipping (Holdings) Limited and ordered six internationally-flagged icebreaker LNG carriers for a project located on the Yamal Peninsula in Northern Russia (or the Yamal LNG Project ). As at December 31, 2016 , the Partnership had advanced $146.7 million to the Yamal LNG Joint Venture ( December 31, 2015 – $96.9 million ). The advances bear interest at LIBOR plus 3.00% compounded semi-annually. As of December 31, 2016 , the interest accrued on these advances was $9.4 million ( December 31, 2015 – $4.8 million ). These amounts are included in the table above. (iii) BG Joint Venture On June 27, 2014, the Partnership acquired from BG (which was subsequently acquired by Shell) its ownership interests in four 174,000 -cubic meter Tri-Fuel Diesel Electric LNG carrier newbuildings, which will be constructed by Hudong-Zhonghua Shipbuilding (Group) Co., Ltd. in China for an estimated total fully built-up cost to the joint venture of approximately $1.0 billion . Through this transaction, the Partnership has a 30% ownership interest in two LNG carrier newbuildings and a 20% ownership interest in the remaining two LNG carrier newbuildings (or collectively, the BG Joint Venture ). As compensation for Shell’s ownership interest in these four LNG carrier newbuildings, the Partnership assumed Shell’s obligation to provide the shipbuilding supervision and crew training services for the four LNG carrier newbuildings up to their delivery date pursuant to a ship construction support agreement. The Partnership estimates it will incur approximately $36.9 million of costs to provide these services, of which Shell has agreed to pay a fixed amount of $20.3 million . The Partnership estimated that the fair value of the service obligation was $33.3 million and the fair value of the amount due from Shell was $16.5 million . As at December 31, 2016 , the carrying value of the service obligation of $22.6 million ( December 31, 2015 – $29.7 million ) is included in both the current portion of in-process contracts and in-process contracts and the carrying value of the receivable from Shell of $10.9 million ( December 31, 2015 – $16.5 million ) is included in both accounts receivable and other assets in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the BG Joint Venture's net assets was $16.8 million ( December 31, 2015 – $16.8 million ). This basis difference has been allocated notionally to the ship construction support agreements and the time-charter contracts. As at December 31, 2016 , to fund its newbuilding installments, the BG Joint Venture has drawn $221.0 million ( December 31, 2015 – $110.3 million ) from its $787.0 million long-term debt facility and received $16.6 million of capital contributions from the Partnership ( December 31, 2015 – $8.6 million ), representing the Partnership’s proportionate share. (iv) Exmar LPG Joint Venture The Partnership has a joint venture agreement with Exmar NV (or Exmar ). In June 2015, Exmar LPG BVBA (or the Exmar LPG Joint Venture ) completed a refinancing of its existing debt facility by entering into a $460.0 million long-term debt facility bearing interest at a rate of LIBOR plus 1.90% , maturing in 2021. The Partnership has guaranteed its 50% share of the secured loan facility in the Exmar LPG Joint Venture and, as a result, recorded a guarantee liability of $1.7 million . The carrying value of the guarantee liability as at December 31, 2016 was $1.3 million ( December 31, 2015 – $1.5 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the Partnership had advanced $52.3 million ( December 31, 2015 – $57.8 million ) to the Exmar LPG Joint Venture, which bears interest at LIBOR plus 0.50% and has no fixed repayment terms. As at December 31, 2016 , the interest accrued on these advances was $1.1 million ( December 31, 2015 – $0.4 million ). These amounts are included in the table above. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the Exmar LPG Joint Venture's net assets was $30.2 million ( December 31, 2015 – $36.4 million ). The basis difference has been accounted for as an adjustment to the value of the vessels and charter agreements of the Exmar LPG Joint Venture and recognition of goodwill in accordance with the finalized purchase price allocation. (v) Teekay LNG-Marubeni Joint Venture The Partnership has a joint venture with Marubeni Corporation and the Partnership (or the Teekay LNG-Marubeni Joint Ventur e). Since control of the Teekay LNG-Marubeni Joint Venture is shared jointly between Marubeni and the Partnership, the Partnership accounts for its investment in the Teekay LNG-Marubeni Joint Venture using the equity method. From June to July 2013, the Teekay LNG Marubeni Joint Venture completed a refinancing of its short-term loan facilities by entering into separate long-term debt facilities totaling approximately $963 million . These debt facilities mature between 2017 and 2030 (see Note 19e). The Partnership has guaranteed its 52% share of the secured loan facilities of the Teekay LNG-Marubeni Joint Venture and, as a result, recorded a guarantee liability of $0.7 million . The carrying value of the guarantee liability as at December 31, 2016 was $0.1 million ( December 31, 2015 – $0.2 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. (vi) Excalibur and Excelsior Joint Ventures The Partnership has joint ventures with Exmar (or the Excalibur Joint Venture and the Excelsior Joint Venture ). In February 2015, the Excalibur and Excelsior Joint Ventures completed refinancing of their existing debt facilities by entering into a $172.8 million long-term debt facility bearing interest at a rate of LIBOR plus 2.75% , maturing in 2019. The Partnership has guaranteed its 50% share of the secured loan facilities of the Excalibur and Excelsior Joint Ventures and, as a result, recorded a guarantee liability of $0.4 million . The carrying value of the guarantee liability as of December 31, 2016 was $0.2 million ( December 31, 2015 – $0.3 million ) and is included as part of other long-term liabilities in the Partnership’s consolidated balance sheets. As at December 31, 2016 , the excess of the carrying value of the Partnership's investment over the carrying value of the Excalibur and Excelsior Joint Venture's net assets was $37.2 million ( December 31, 2015 – $38.6 million ). The basis difference has substantially been accounted for as an increase to the carrying value of the vessels of the Excalibur and Excelsior Joint Ventures in accordance with the finalized purchase price allocation. (vii) Angola Joint Venture The Partnership has a 33% ownership interest in a joint venture (or the Angola Joint Venture ) that owns four 160,400 -cubic meter LNG carriers (or the Angola LNG Carriers ). The other partners of the Angola Joint Venture are NYK Energy Transport (or NYK ) ( 33% ) and Mitsui & Co. Ltd. ( 34% ). (viii) RasGas 3 Joint Venture The Partnership has a 40% ownership interest in Teekay Nakilat (III) Corporation (or the RasGas 3 Joint Venture ), and the remaining 60% is held by Qatar Gas Transport Company Ltd. (Nakilat). b) The RasGas 3 Joint Venture, the Excelsior Joint Venture, the Angola Joint Venture, the Yamal LNG Joint Venture, and the Bahrain LNG Joint Venture are considered variable interest entities; however, the Partnership is not the primary beneficiary and consolidation of these entities with the Partnership is not required. The Partnership’s maximum exposure to loss as a result of its investment in the RasGas 3 Joint Venture, the Excelsior Joint Venture, the Angola LNG Joint Venture, the Yamal LNG Joint Venture, and the Bahrain LNG Joint Venture is the amount it has invested and advanced in these joint ventures, which are $174.6 million , $50.3 million , $65.6 million , $152.7 million and $63.9 million , respectively, as at December 31, 2016 . In addition, the Partnership guarantees its portion of the Excelsior Joint Venture’s debt of $45.0 million and the Angola Joint Ventures’ debt and swaps of $256.1 million and provides a guarantee against a charter termination. The carrying value of Angola Joint Venture's guarantee liability as of December 31, 2016 was $1.0 million ( December 31, 2015 – $1.2 million ) and is included as part of other liabilities in the Partnership’s consolidated balance sheets. c) The follo wing table presents aggregated summarized financial information reflecting a 100% ownership interest in the Partnership’s equity method investments and excluding the impact from purchase price adjustments arising from the acquisition of Exmar LPG BVBA, the Excalibur and Excelsior Joint Ventures and the BG Joint Venture. The results include the Excalibur and Excelsior Joint Ventures, the RasGas 3 Joint Venture, the Angola Joint Venture, the Exmar LPG Joint Venture, the Teekay LNG-Marubeni Joint Venture, the BG Joint Venture from June 2014, the Yamal LNG Joint Venture from July 2014, and the Bahrain LNG Joint Venture from December 2015. As at December 31, 2016 2015 Cash and restricted cash – current 388,007 281,943 Other assets – current 111,847 77,861 Vessels and equipment 2,837,870 2,343,397 Net investments in direct financing leases – non-current 1,776,954 1,813,991 Other assets – non-current 37,132 22,120 Current portion of long-term debt and obligations under capital lease 209,814 166,522 Other liabilities – current 102,385 97,405 Long-term debt and obligations under capital lease 3,233,425 2,787,055 Other liabilities – non-current 157,025 177,879 Years ended December 31, 2016 2015 2014 Voyage revenues 549,646 596,093 640,105 Income from vessel operations 268,049 302,731 398,836 Realized and unrealized loss on non-designated derivative instruments (12,277 ) (25,108 ) (52,938 ) Net income 167,052 203,280 267,990

Intangible Assets and Goodwill

Intangible Assets and Goodwill (Tables)	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Carrying Amount of Intangible Assets for Partnership's Reportable Segments	The carrying amount of intangible assets for the Partnership’s liquefied gas segment is as follows: December 31 December 31 Gross carrying amount 179,813 179,813 Accumulated amortization (109,879 ) (101,023 ) Net carrying amount 69,934 78,790

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2016
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities	December 31 December 31 Interest including interest rate swaps 19,957 17,484 Voyage and vessel expenses 9,311 9,315 Payroll and benefits 3,355 5,431 Other general expenses 3,069 2,785 Income tax payable and other 189 2,441 Total 35,881 37,456

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Components of Long-Term Debt	December 31, 2016 December 31, 2015 $ $ U.S. Dollar-denominated Revolving Credit Facilities due from 2017 to 2018 208,222 329,222 U.S. Dollar-denominated Term Loans due from 2018 to 2026 1,005,199 1,150,436 Norwegian Kroner-denominated Bonds due from 2017 to 2021 371,329 294,016 Euro-denominated Term Loans due from 2018 to 2023 219,733 241,798 Total principal 1,804,483 2,015,472 Unamortized discount and debt issuance costs (13,257 ) (16,263 ) Total debt 1,791,226 1,999,209 Less current portion (188,511 ) (197,197 ) Long-term debt 1,602,715 1,802,012

Income Tax (Tables)

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Components of Provision for Income Taxes	The components of the provision for income taxes were as follows: Year Ended Year Ended Year Ended Current (962 ) (2,646 ) (5,212 ) Deferred (11 ) (76 ) (2,355 ) Income tax expense (973 ) (2,722 ) (7,567 )
Reconciliations of Tax Charge	Reconciliations of the tax charge related to the relevant year at the applicable statutory income tax rates and the actual tax charge related to the relevant year are as follows: Year Ended Year Ended Year Ended Net income before income tax expenses 158,938 220,232 226,494 Net income not subject to taxes (138,542 ) (173,298 ) (81,604 ) Net income subject to taxes 20,396 46,934 144,890 At applicable statutory tax rates Amount computed using the standard rate of corporate tax (3,338 ) (12,007 ) (33,083 ) Adjustments to valuation allowance and uncertain tax positions 11,802 5,362 14,851 Permanent and currency differences (9,125 ) 4,204 11,507 Change in tax rate (312 ) (281 ) (842 ) Tax expense related to the current year (973 ) (2,722 ) (7,567 )
Components of Partnership's Deferred Tax Assets (Liabilities)	The significant components of the Partnership’s deferred tax assets (liabilities) were as follows: Year Ended Year Ended Derivative instruments 4,523 7,021 Taxation loss carryforwards and disallowed finance costs 34,927 44,823 Vessels and equipment 3,554 3,462 Capitalized interest (2,027 ) (2,184 ) 40,977 53,122 Valuation allowance (41,064 ) (53,198 ) Net deferred tax liabilities included in accrued liabilities (87 ) (76 )

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Such related party transactions were as follows for the periods indicated: Year Ended December 31 December 31 December 31 Voyage revenues (i) 37,336 35,887 37,596 Vessel operating expenses (20,438 ) (19,914 ) (12,703 ) General and administrative expenses (ii) (11,890 ) (14,485 ) (13,708 ) General and administrative expenses deferred and capitalized (iii) (571 ) — — (i) Commencing in 2008, the Arctic Spiri t and Polar Spirit were time-chartered to Teekay Corporation at a fixed-rate for a period of 10 years (plus options exercisable by Teekay Corporation to extend up to an additional 15 years ). (ii) Includes commercial, strategic, advisory, business development and administrative management fees charged by Teekay Corporation and reimbursements to Teekay Corporation and our General Partner for costs incurred on the Partnership’s behalf. (iii) Includes the Partnership's proportionate costs associated with the Bahrain LNG Joint Venture including pre-operation, engineering and financing-related expenses, of which $0.4 million was reimbursed by the Bahrain LNG Joint Venture during 2016. The net costs are recorded as part of investments in and advances to equity accounted joint ventures in the Partnership's consolidated balance sheets.

Derivative Instruments and He40

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of Cross Currency Swap Agreements	The following table reflects information relating to the cross-currency swaps as at December 31, 2016 . Floating Rate Receivable Principal Principal Reference Margin Fixed Rate Fair Value / Weighted- 408,500 72,946 NIBOR 5.25 % 6.88 % (26,417 ) 0.3 900,000 150,000 NIBOR 4.35 % 6.43 % (49,655 ) 1.7 1,000,000 134,000 NIBOR 3.70 % 5.92 % (19,900 ) 3.4 900,000 110,400 NIBOR 6.00 % 7.72 % (3,814 ) 4.8 (99,786 )
Interest Rate Swap Agreements	At December 31, 2016 , the terms of the interest rate swaps underlying the interest rate swaptions were as follows: Interest Principal Option Fair Value / Remaining Interest Interest rate swaption - Call Option LIBOR 155,000 (i) April 28, 2017 31 7.5 3.3 Interest rate swaption - Put Option LIBOR 155,000 (i) April 28, 2017 (1,525 ) 7.5 2.2 Interest rate swaption - Call Option LIBOR 160,000 (ii) January 31, 2018 1,140 8.0 3.1 Interest rate swaption - Put Option LIBOR 160,000 (ii) January 31, 2018 (1,457 ) 8.0 2.0 Interest rate swaption - Call Option LIBOR 160,000 (iii) July 16, 2018 2,112 8.0 2.9 Interest rate swaption - Put Option LIBOR 160,000 (iii) July 16, 2018 (1,248 ) 8.0 1.8 (i) Amortizing every three months from $155.0 million in April 2017 to $85.4 million in October 2024. (ii) Amortizing every three months from $160.0 million in January 2018 to $82.5 million in January 2026. (iii) Amortizing every three months from $160.0 million in July 2018 to $82.5 million in July 2026. As at December 31, 2016 , the Partnership was committed to the following interest rate swap agreements: Interest Principal Fair Value / Weighted- Fixed Interest Rate (%) (i) LIBOR-Based Debt: U.S. Dollar-denominated interest rate swaps LIBOR 90,000 (5,748 ) 1.7 4.9 U.S. Dollar-denominated interest rate swaps LIBOR 100,000 (1,145 ) 0.0 5.3 U.S. Dollar-denominated interest rate swaps (ii) LIBOR 156,250 (26,765 ) 12.0 5.2 U.S. Dollar-denominated interest rate swaps (ii) LIBOR 53,557 (1,494 ) 4.6 2.8 U.S. Dollar-denominated interest rate swaps (iii) LIBOR 320,000 (17,079 ) 1.0 3.4 U.S. Dollar-denominated interest rate swaps (iv) LIBOR 108,333 (665 ) 2.0 1.7 U.S. Dollar-denominated interest rate swaps (v) LIBOR 197,629 590 9.2 2.3 EURIBOR-Based Debt: Euro-denominated interest rate swaps (vi) EURIBOR 219,733 (34,295 ) 4.0 3.1 (86,601 ) (i) Excludes the margins the Partnership pays on its floating-rate term loans, which, at December 31, 2016 , ranged from 0.30% to 2.80% . (ii) Principal amount reduces semi-annually. (iii) These interest rate swaps are being used to economically hedge expected interest payments on future debt that is planned to be outstanding from 2017 to 2024. These interest rate swaps are subject to mandatory early termination in 2017 and 2018 whereby the swaps will be settled based on their fair value at that time. (iv) Principal amount reduces quarterly. (v) Principal amount reduces quarterly commencing December 2017. (vi) Principal amount reduces monthly to 70.1 million Euros ( $73.7 million ) by the maturity dates of the swap agreements.
Location and Fair Value Amounts of Derivative Instruments	The following table presents the location and fair value amounts of derivative instruments, segregated by type of contract, on the Partnership’s consolidated balance sheets. Derivative Accrued Current Derivative As at December 31, 2016 Interest rate swap agreements — — 1,080 (5,514 ) (22,432 ) (59,735 ) Interest rate swaption agreements — 31 3,252 — (1,525 ) (2,705 ) Cross-currency swap agreements — — — (1,090 ) (32,843 ) (65,853 ) Toledo Spirit time-charter derivative 1,274 500 360 — — — 1,274 531 4,692 (6,604 ) (56,800 ) (128,293 ) As at December 31, 2015 Interest rate swap agreements — — — (6,833 ) (41,028 ) (56,276 ) Interest rate swaption agreements — — 5,623 — — (6,406 ) Cross-currency swap agreements — — — (1,181 ) (9,755 ) (117,846 ) Toledo Spirit time-charter derivative — — — (3,186 ) (1,300 ) (1,810 ) — — 5,623 (11,200 ) (52,083 ) (182,338 )
Gain (Loss) for Derivative Instruments Not Designated or Qualifying as Hedging Instruments	The effect of the gain (loss) on these derivatives on the Partnership's consolidated statements of income is as follows: Year Ended December 31, 2016 2015 2014 Realized Unrealized Total Realized Unrealized Total Realized Unrealized Total Cross-currency swap agreements (9,063 ) 28,905 19,842 (7,640 ) (57,759 ) (65,399 ) (2,222 ) (51,762 ) (53,984 ) Cross-currency swap agreements termination (17,711 ) — (17,711 ) — — — — — — (26,774 ) 28,905 2,131 (7,640 ) (57,759 ) (65,399 ) (2,222 ) (51,762 ) (53,984 ) The effect of the gain (loss) on these derivatives on the Partnership’s consolidated statements of income is as follows: Year Ended December 31, 2016 2015 2014 Realized Unrealized Total Realized Unrealized Total Realized Unrealized Total Interest rate swap agreements (25,940 ) 15,627 (10,313 ) (28,968 ) 14,768 (14,200 ) (39,406 ) 4,204 (35,202 ) Interest rate swaption agreements — (164 ) (164 ) — (783 ) (783 ) — — — Interest rate swap agreements termination — — — — — — (2,319 ) — (2,319 ) Toledo Spirit time-charter derivative (654 ) 3,970 3,316 (3,429 ) (1,610 ) (5,039 ) (861 ) (6,300 ) (7,161 ) (26,594 ) 19,433 (7,161 ) (32,397 ) 12,375 (20,022 ) (42,586 ) (2,096 ) (44,682 )
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)	The following table excludes any interest rate swap agreements designated and qualifying as cash flow hedges in the Partnership’s equity accounted joint ventures. Year Ended December 31, 2016 Effective Portion Recognized in AOCI (i) $ Effective Portion Reclassified from AOCI (ii) $ Ineffective Portion (iii) $ 590 — — Interest expense 590 — — (i) Effective portion of designated and qualifying cash flow hedges recognized in other comprehensive income (loss). (ii) Effective portion of designated and qualifying cash flow hedges recorded in accumulated other comprehensive income (loss) (or AOCI ) during the term of the hedging relationship and reclassified to earnings. (iii) Ineffective portion of designated and qualifying cash flow hedges.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Partnership’s Share of Commitments to Fund Newbuilding and Other Construction Contract Costs	The Partnership’s share of commitments to fund newbuilding and other construction contract costs as at December 31, 2016 are as follows: Total 2017 2018 2019 2020 DSME (i) 1,118,345 627,181 491,164 — — Hyundai Samho Heavy Industries Co. (ii) 378,347 82,507 45,533 250,307 — Yamal LNG Joint Venture (iii) 883,030 91,800 344,850 247,800 198,580 BG Joint Venture (iv) 195,565 80,010 86,154 29,401 — Bahrain LNG Joint Venture (v) 224,080 110,364 80,097 33,619 — Exmar LPG Joint Venture (vi) 77,504 58,096 19,408 — — 2,876,871 1,049,958 1,067,206 561,127 198,580 (i) As at December 31, 2016 , the Partnership had seven LNG carrier newbuildings on order with DSME which are scheduled for delivery between 2017 and 2019. As at December 31, 2016 , costs incurred under these newbuilding contracts totaled $316.1 million . The Partnership has secured $682.8 million of financing during 2016 related to the commitments for four LNG carrier newbuildings included in the table above (see Note 5) and in April 2017, secured $174.3 million of additional financing for one LNG carrier newbuilding included in the table above. (ii) As at December 31, 2016 , the Partnership had two LNG carrier newbuildings on order with Hyundai Samho Heavy Industries Co. (or HHI ) scheduled for delivery in 2019. As at December 31, 2016 , costs incurred under these newbuilding contracts totaled $41.5 million . The Partnership intends to finance the newbuilding payments through existing liquidity and expects to secure long-term debt financing for the vessels prior to their scheduled deliveries. (iii) The Partnership, through the Yamal LNG Joint Venture, has a 50% ownership interest in six 172,000 -cubic meter ARC7 LNG carrier newbuildings that have an estimated total fully built-up cost of $2.1 billion . As at December 31, 2016 , the Partnership’s proportionate costs incurred under these newbuilding contracts totaled $153.3 million . The Yamal LNG Joint Venture intends to secure debt financing for the six LNG carrier newbuildings prior to their scheduled deliveries. (iv) The Partnership acquired an ownership interest in the BG Joint Venture and, as part of the acquisition, agreed to assume Shell’s obligation to provide shipbuilding supervision and crew training services for the four LNG carrier newbuildings up to their delivery dates pursuant to a ship construction support agreement. The BG Joint Venture has secured financing of $137.1 million related to the commitments included in the table above and the Partnership is scheduled to receive $10.9 million of reimbursement directly from Shell. (v) The Partnership has a 30% ownership interest in the Bahrain LNG Joint Venture for the development of an LNG receiving and regasification terminal in Bahrain. The project will include a FSU, which will be modified from one of the Partnership’s existing MEGI LNG carrier newbuildings, an offshore gas receiving facility, and an onshore nitrogen production facility. The terminal will have a capacity of 800 million standard cubic feet per day and will be owned and operated under a 20 -year agreement commencing early-2019. The receiving and regasification terminal is expected to have a fully-built up cost of approximately $960.0 million . The Bahrain LNG Joint Venture has secured debt financing for approximately 75% of the estimated fully built-up cost of the LNG receiving and regasification terminal in Bahrain. (vi) The Partnership has a 50% ownership interest in the Exmar LPG Joint Venture which has four LPG newbuilding vessels scheduled for delivery between 2017 and 2018 and has secured financing for the four LPG carrier newbuildings.

Supplemental Cash Flow Inform42

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Changes in Operating Assets and Liabilities	The changes in operating assets and liabilities for years ended December 31, 2016 , 2015 and 2014 are as follows: Year Ended Year Ended Year Ended Accounts receivable 5,494 (5,140 ) 9,957 Prepaid expenses 745 (494 ) 1,781 Accounts payable 2,791 2,127 (1,098 ) Accrued liabilities (1,572 ) (1,581 ) (6,759 ) Unearned revenue and long-term unearned revenue (3,218 ) (562 ) (536 ) Restricted cash (10,808 ) (2,785 ) — Advances to and from affiliates (9,699 ) (23,714 ) 17,953 Other operating assets and liabilities (4,402 ) (2,038 ) (2,476 ) Total (20,669 ) (34,187 ) 18,822

Total Capital and Net Income 43

Total Capital and Net Income Per Common Unit (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Incentive Distributions	The General Partner is entitled to incentive distributions if the amount the Partnership distributes to common 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 $0.4125 98 % 2 % Up to $0.4625 98 % 2 % Above $0.4625 up to $0.5375 85 % 15 % Above $0.5375 up to $0.6500 75 % 25 % Above $0.6500 50 % 50 %
Issuances of Common Units	The following table summarizes the issuances of common and preferred units over the three years ending December 31, 2016 : Date Units Type of Units Offering Gross Proceeds (i) $ Net Proceeds $ Teekay Corporation’s Ownership After the Offering (ii) Use of Proceeds July 2014 Public Offering 3,090,000 Common $ 44.65 140,784 140,484 33.96 % Prepayment of revolving credit facilities, funding of the Yamal LNG Project and funding newbuilding installments Continuous offering program during 2014 1,050,463 Common (iii) 42,556 41,655 (iii) General partnership purposes including funding newbuilding installments Continuous offering program during 2015 (iv) 1,173,428 Common (iii) 36,274 35,374 (iii) General partnership purposes, including funding newbuilding installments October 2016 Public Offering (v) 5,000,000 Preferred $ 25.00 125,000 120,707 (v) General partnership purposes, including debt repayments and funding newbuilding installments (i) Including the General Partner’s 2% proportionate capital contribution. (ii) Including Teekay Corporation’s indirect 2% general partner interest relating to common unit offerings. (iii) Commencing in May 2013, the Partnership implemented a continuous offering program (or COP ) under which the Partnership may issue new common units, representing limited partner interests, from time to time at market prices up to a maximum aggregate amount of $100 million . (iv) Includes 160,000 common units sold under the COP in December 2014 for which net proceeds of $6.8 million (including the General Partner’s 2% proportionate capital contribution) were received in January 2015. (v) On October 5, 2016, the Partnership issued Series A Preferred Units at a rate of 9.0% per annum of the stated liquidation preference of $25.00 per unit. At any time on or after October 5, 2021, the Partnership may redeem the Series A Preferred Units, in whole or in part, at a redemption price of $25.00 per unit plus all accumulated and unpaid distributions to the date of redemption, whether or not declared.

Summary of Significant Accoun44

Summary of Significant Accounting Policies - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)vessel	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Depreciation of vessels and equipment | $	$ 86.6	$ 83.4	$ 70.1
Interest costs capitalized to vessels and equipment | $	$ 9.9	$ 8.2	$ 3.1
Number of vessels | vessel	35,000
Spain
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of vessels | vessel	2
Tax rate in Spain	25.00%
Effective income tax rate on revenue by Spanish vessels tax credit	90.00%
Effective tax rate on revenues by Spanish vessels	2.50%
Conventional Tankers Segment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Estimated useful life in years	25 years
Liquefied Petroleum Gas
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Estimated useful life in years	30 years
Liquefied Natural Gas
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Estimated useful life in years	35 years
Dry-docking Activity
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Estimated useful life in years	5 years

Summary of Significant Accoun45

Summary of Significant Accounting Policies - Changes in Partnership's Capitalized Dry Docking Costs (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Roll Forward]
Beginning balance	$ 2,108,160
Cost incurred for dry docking	13,944	$ 10,357	$ 13,471
Ending balance	2,215,983	2,108,160
Dry-docking Activity
Property, Plant and Equipment [Roll Forward]
Beginning balance	33,916	33,635	40,328
Cost incurred for dry docking	13,944	10,357	13,471
Sales of vessels	(2,886)	0	(5,327)
Dry-dock amortization	(11,436)	(10,076)	(14,837)
Ending balance	$ 33,538	$ 33,916	$ 33,635

Summary of Significant Accoun46

Summary of Significant Accounting Policies - Changes in Balances of Component of Accumulated Other Comprehensive (Loss) Income (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 1,543,679	$ 1,547,371	$ 1,443,784
Other comprehensive loss	2,803	(648)	(1,534)
Ending balance	1,777,412	1,543,679	1,547,371
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(2,051)	(1,403)	131
Other comprehensive loss	2,626	(648)	(1,534)
Ending balance	$ 575	$ (2,051)	$ (1,403)

Financial Instruments - Schedul

Financial Instruments - Schedule of Estimated Fair Value of Partnership's Financial Instruments on Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Vessel held for sale	$ 20,580	$ 0
Long-term debt	(1,791,226)	(1,999,209)
Carrying Amount Asset (Liability) $
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Advances to equity accounted joint ventures (note 6)	272,514	159,870
Carrying Amount Asset (Liability) $ | Level 1 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents and restricted cash	243,173	214,000
Carrying Amount Asset (Liability) $ | Level 2 | Non-recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Vessel held for sale	20,580	0
Carrying Amount Asset (Liability) $ | Level 2 | Interest rate swap agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap agreements – assets	1,080	0
Interest rate swap agreements – liabilities	(87,681)	(104,137)
Carrying Amount Asset (Liability) $ | Level 2 | Interest rate swaption agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaption agreements – assets	3,283	5,623
Interest rate swaption agreements – liabilities	(4,230)	(6,406)
Carrying Amount Asset (Liability) $ | Level 2 | Cross-currency swap agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cross-currency swap agreements	(99,786)	(128,782)
Carrying Amount Asset (Liability) $ | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivable included in accounts receivable and other assets	10,985	16,453
Carrying Amount Asset (Liability) $ | Level 3 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other derivative	2,134	(6,296)
Fair Value Asset (Liability) $ | Level 1 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents and restricted cash	243,173	214,000
Fair Value Asset (Liability) $ | Level 2 | Non-recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Vessel held for sale	20,580	0
Fair Value Asset (Liability) $ | Level 2 | Interest rate swap agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap agreements – assets	1,080	0
Interest rate swap agreements – liabilities	(87,681)	(104,137)
Fair Value Asset (Liability) $ | Level 2 | Interest rate swaption agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaption agreements – assets	3,283	5,623
Interest rate swaption agreements – liabilities	(4,230)	(6,406)
Fair Value Asset (Liability) $ | Level 2 | Cross-currency swap agreements | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cross-currency swap agreements	(99,786)	(128,782)
Fair Value Asset (Liability) $ | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivable included in accounts receivable and other assets	10,944	16,427
Fair Value Asset (Liability) $ | Level 3 | Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other derivative	2,134	(6,296)
Public | Carrying Amount Asset (Liability) $ | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	(368,612)	(291,247)
Public | Fair Value Asset (Liability) $ | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	(366,418)	(288,333)
Non-public | Carrying Amount Asset (Liability) $ | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	(1,422,614)	(1,707,962)
Non-public | Fair Value Asset (Liability) $ | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ (1,381,287)	$ (1,677,139)

Financial Instruments - Sched48

Financial Instruments - Schedule of Estimated Fair Value of Partnership's Financial Instruments on Recurring Basis (Footnotes) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value Asset (Liability) $ | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivable and accrued revenue included in accounts receivable and other assets	$ 10,944	$ 16,427
BG Joint Venture | Shipbuilding supervision and crew training services
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Discount rate over remaining duration of contract	8.00%
BG Joint Venture | Shipbuilding supervision and crew training services | Fair Value Asset (Liability) $ | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivable and accrued revenue included in accounts receivable and other assets	$ 10,900

Financial Instruments - Changes

Financial Instruments - Changes in Fair Value of Asset Measured on Recurring Basis Using Significant Unobservable Inputs (Level 3) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value at beginning of year	$ (6,296)	$ (2,137)
Realized and unrealized gains (losses) included in earnings	3,316	(5,039)
Settlements	5,114	880
Fair value at end of year	$ 2,134	$ (6,296)

Financial Instruments - Additio

Financial Instruments - Additional Information (Detail) - Toledo Spirit time-charter derivative - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Average daily tanker rate over remaining duration of charter contract	$ 22,875	$ 34,093
Discount rate over remaining duration of contract	8.40%	7.50%

Financial Instruments - Summary

Financial Instruments - Summary of Partnership's Loan Receivables and Other Financing Receivables (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Financing Receivable, Recorded Investment [Line Items]
Direct financing leases	$ 643,008	$ 666,658
Other receivables:
Total loans receivables and other financing receivables	927,693	854,784
Performing | Payment activity
Financing Receivable, Recorded Investment [Line Items]
Direct financing leases	643,008	666,658
Other receivables:
Long-term receivable and accrued revenue included in accounts receivable and other assets	12,171	28,256
Performing | Other internal metrics
Other receivables:
Advances to equity accounted joint ventures	$ 272,514	$ 159,870

Segment Reporting - Additional

Segment Reporting - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016vesselsegment
Segment Reporting Information [Line Items]
Number of reportable segments | segment	2
Number of vessels	35,000
Liquefied Gas Segment | Liquefied Natural Gas
Segment Reporting Information [Line Items]
Number of vessels	50
Liquefied Gas Segment | Liquefied Natural Gas | Corporate Joint Venture
Segment Reporting Information [Line Items]
Number of vessels	26
Liquefied Gas Segment | Liquefied Petroleum Gas Multi Gas
Segment Reporting Information [Line Items]
Number of vessels in partnership	29
Liquefied Gas Segment | Liquefied Petroleum Gas Multi Gas | Corporate Joint Venture
Segment Reporting Information [Line Items]
Number of vessels in partnership	23
Conventional Tankers Segment | Suezmax Tankers
Segment Reporting Information [Line Items]
Number of vessels in partnership	5
Conventional Tankers Segment | Handymax Product
Segment Reporting Information [Line Items]
Number of vessels in partnership	1

Segment Reporting - Revenues an

Segment Reporting - Revenues and Percentage of Consolidated Voyage Revenues from Top Customers (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenue, Major Customer [Line Items]
Voyage revenues from major customers	$ 396,444	$ 397,991	$ 402,928
Customer Concentration Risk | Ras Laffan Liquefied Natural Gas Company Ltd.
Revenue, Major Customer [Line Items]
Voyage revenues from major customers	$ 70,300	$ 70,100	$ 69,800
Customer Concentration Risk | Ras Laffan Liquefied Natural Gas Company Ltd. | Sales Revenue, Net
Revenue, Major Customer [Line Items]
Percentage of voyage revenues from major customers	18.00%	18.00%	17.00%
Customer Concentration Risk | Shell Spain LNG S.A.U
Revenue, Major Customer [Line Items]
Voyage revenues from major customers	$ 48,200	$ 48,500	$ 51,800
Customer Concentration Risk | Shell Spain LNG S.A.U | Sales Revenue, Net
Revenue, Major Customer [Line Items]
Percentage of voyage revenues from major customers	12.00%	12.00%	13.00%
Customer Concentration Risk | The Tangguh Production Sharing Contractors
Revenue, Major Customer [Line Items]
Voyage revenues from major customers	$ 44,400	$ 44,900	$ 44,300
Customer Concentration Risk | The Tangguh Production Sharing Contractors | Sales Revenue, Net
Revenue, Major Customer [Line Items]
Percentage of voyage revenues from major customers	11.00%	11.00%	11.00%

Segment Reporting - Segment Rep

Segment Reporting - Segment Reporting Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Voyage revenues	$ 396,444	$ 397,991	$ 402,928
Voyage recoveries (expenses)	(1,656)	(1,146)	(3,321)
Vessel operating expenses	(88,590)	(94,101)	(95,808)
Depreciation and amortization	(95,542)	(92,253)	(94,127)
General and administrative expenses	(18,499)	(25,118)	(23,860)
Write-down and loss on sale of vessels	(38,976)	0	0
Restructuring charges	0	(4,001)	(1,989)
Income (loss) from vessel operations	153,181	181,372	183,823
Equity income	62,307	84,171	115,478
Investment in and advances to equity accounted joint ventures	1,037,726	883,731
Total assets	4,150,641	3,910,923
Expenditures for vessels and equipment	(344,987)	(191,969)	(194,255)
Expenditures for dry docking	(13,944)	(10,357)	(13,471)
Liquefied Gas Segment
Segment Reporting Information [Line Items]
Voyage revenues	336,530	305,056	307,426
Voyage recoveries (expenses)	(449)	203	(1,768)
Vessel operating expenses	(66,087)	(63,344)	(59,087)
Depreciation and amortization	(80,084)	(71,323)	(71,711)
General and administrative expenses	(15,310)	(19,392)	(17,992)
Write-down and loss on sale of vessels	0
Restructuring charges		0	0
Income (loss) from vessel operations	174,600	151,200	156,868
Equity income	62,307	84,171	115,478
Investment in and advances to equity accounted joint ventures	1,037,726	883,731
Total assets	3,957,088	3,550,396
Expenditures for vessels and equipment	(344,924)	(191,642)	(193,669)
Expenditures for dry docking	(13,944)	(8,659)	(8,127)
Conventional Tankers Segment
Segment Reporting Information [Line Items]
Voyage revenues	59,914	92,935	95,502
Voyage recoveries (expenses)	(1,207)	(1,349)	(1,553)
Vessel operating expenses	(22,503)	(30,757)	(36,721)
Depreciation and amortization	(15,458)	(20,930)	(22,416)
General and administrative expenses	(3,189)	(5,726)	(5,868)
Write-down and loss on sale of vessels	(38,976)
Restructuring charges		(4,001)	(1,989)
Income (loss) from vessel operations	(21,419)	30,172	26,955
Equity income	0	0	0
Investment in and advances to equity accounted joint ventures	0	0
Total assets	193,553	360,527
Expenditures for vessels and equipment	(63)	(327)	(586)
Expenditures for dry docking	$ 0	$ (1,698)	$ (5,344)

Segment Reporting - Reconciliat

Segment Reporting - Reconciliation of Total Segment Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Total assets	$ 4,150,641	$ 3,910,923
Unallocated:
Cash and cash equivalents	126,146	102,481	$ 159,639	$ 139,481
Accounts receivable and prepaid expenses	28,948	26,550
Advances to affiliates	9,739	13,026
Total assets	4,315,474	4,052,980
Liquefied Gas Segment
Segment Reporting Information [Line Items]
Total assets	3,957,088	3,550,396
Conventional Tankers Segment
Segment Reporting Information [Line Items]
Total assets	$ 193,553	$ 360,527

Leases and Restricted Cash - Ca

Leases and Restricted Cash - Capital Lease Obligations (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Capital Leased Assets [Line Items]
Total obligations under capital lease	$ 392,839	$ 59,127
Less current portion	(40,353)	(4,546)
Long-term obligations under capital lease	352,486	54,581
LNG Carriers
Capital Leased Assets [Line Items]
Total obligations under capital lease	338,257	0
Suezmax Tankers
Capital Leased Assets [Line Items]
Total obligations under capital lease	$ 54,582	$ 59,127

Leases and Restricted Cash - 57

Leases and Restricted Cash - Capital Lease Obligations - Additional Information (Detail) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2016	Dec. 31, 2016USD ($)vesselleasebuilding
Capital Leased Assets [Line Items]
Number of capital leases | lease		2
Number of vessels | vessel		35,000
LNG Carriers
Capital Leased Assets [Line Items]
Number of capital leases | lease		2
Term of contract	10 years
Sale leaseback amount		$ 682.8
Number of carrier newbuildings | building		4
Related purchase obligations		$ 478.1
Interest included in payments		$ 139.8
Suezmax Tankers
Capital Leased Assets [Line Items]
Number of capital leases | vessel		2
Weighted-average interest rate on lease		5.50%
Related purchase obligations		$ 58.2
Interest included in payments		$ 3.6
Number of vessels | vessel		2
Capital lease arrangement period, lessee		Under these capital leases, the owner has the option to require the Partnership to purchase the two vessels. The charterer, who is also the owner, also has the option to cancel the charter contracts and the cancellation options are first exercisable in October 2017 and July 2018, respectively.
Newbuildings
Capital Leased Assets [Line Items]
Number of vessels | vessel		15,000
Newbuildings | LNG Carriers
Capital Leased Assets [Line Items]
Number of carrier newbuildings | building		4

Leases and Restricted Cash - Co

Leases and Restricted Cash - Commitment Under Capital Leases (Detail) $ in Thousands	Dec. 31, 2016USD ($)
LNG Carriers
Commitment
2,017	$ 30,065
2,018	30,065
2,019	30,065
2,020	30,147
2,021	30,065
Thereafter	327,686
Suezmax Tankers
Commitment
2,017	30,953
2,018	$ 27,296

Leases and Restricted Cash - Re

Leases and Restricted Cash - Restricted Cash - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Leases [Abstract]
Restricted cash on deposits relating to certain term loans, collateral cross currency swaps, project tenders, leasing arrangements, dry-docking expenditures and emergency repairs	$ 117	$ 111.5

Leases and Restricted Cash - Op

Leases and Restricted Cash - Operating Lease Obligations - Additional Information (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)vessel	Dec. 31, 2015USD ($)
Property Subject to or Available for Operating Lease [Line Items]
Number of vessels	35,000
Teekay Tangguh Joint Venture
Property Subject to or Available for Operating Lease [Line Items]
Number of vessels	2
Tax indemnification | $	$ 7.5	$ 8
Tax indemnification of lease contracts	The tax indemnification is for the duration of the lease contract with the third party plus the years it would take for the lease payments to be statute barred, and ends in 2033.
Operating lease arrangement period, lessor	20 years

Leases and Restricted Cash - Es

Leases and Restricted Cash - Estimated Future Minimum Rental Payments to be Received and Paid Under the Lease Contracts (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Head Lease Receipts
Head Lease Receipts
2,017	$ 21,242
2,018	21,242
2,019	21,242
2,020	21,242
2,021	21,242
Thereafter	154,095
Total	260,305
Sublease Payments
Sublease Payments
2,017	24,113
2,018	24,113
2,019	24,113
2,020	24,113
2,021	24,113
Thereafter	174,959
Total	$ 295,524

Leases and Restricted Cash - 62

Leases and Restricted Cash - Estimated Future Minimum Rental Payments to be Received and Paid Under the Lease Contracts (Footnotes) (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Operating Leased Assets [Line Items]
Deferred head lease receipts, unearned revenue	$ 16,998	$ 19,608
Teekay Tangguh Joint Venture
Operating Leased Assets [Line Items]
Head lease receipts	250,000
Sublease payments made	187,900
Deferred head lease receipts, unearned revenue	3,700	3,800
Teekay Tangguh Joint Venture | Other Noncurrent Liabilities
Operating Leased Assets [Line Items]
Deferred head lease receipts, long-term liabilities	$ 36,700	$ 40,400

Leases and Restricted Cash - Ne

Leases and Restricted Cash - Net Investments in Direct Financing Leases - Additional Information (Detail) $ in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Jul. 31, 2016USD ($)	Nov. 30, 2013USD ($)vesselm³	Dec. 31, 2016USD ($)vessel	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Capital Leased Assets [Line Items]
Number of vessels | vessel			35,000
Acquisition cost of vessels and associated fixed-rate contracts			$ 344,987	$ 191,969	$ 194,255
Awilco LNG Carriers
Capital Leased Assets [Line Items]
Number of vessels | vessel		2
Volume of vessels (in cubic meter) | m³		155,900
Additional time period for fixed rate time charters contract			1 year
Upfront fee		$ 1,000
Minimum scheduled future revenues, capital lease, 2017			$ 162,000
Minimum scheduled future revenues, capital lease, 2018			$ 134,600
Awilco LNG Carriers | Vessel One
Capital Leased Assets [Line Items]
Operating lease arrangement period, lessor			5 years
Acquisition cost of vessels and associated fixed-rate contracts		205,000
Upfront prepayment of charter for hire		$ 51,000
Awilco LNG Carriers | Vessel Two
Capital Leased Assets [Line Items]
Operating lease arrangement period, lessor			4 years
Acquisition cost of vessels and associated fixed-rate contracts	$ 205,000
Upfront prepayment of charter for hire	$ 51,000
Teekay Tangguh Joint Venture
Capital Leased Assets [Line Items]
Capital lease arrangement period, lessor			20-year
Number of vessels | vessel			2
Operating lease arrangement period, lessor			20 years
Minimum scheduled future revenues, capital lease, 2017			$ 39,100
Minimum scheduled future revenues, capital lease, 2018			39,100
Minimum scheduled future revenues, capital lease, 2019			39,100
Minimum scheduled future revenues, capital lease, 2020			39,100
Minimum scheduled future revenues, capital lease, 2021			$ 39,100

Leases and Restricted Cash - 64

Leases and Restricted Cash - Net Investments in Direct Financing Leases (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Leases [Abstract]
Total minimum lease payments to be received	$ 764,970	$ 843,079
Estimated unguaranteed residual value of leased properties	194,965	194,965
Initial direct costs	393	425
Less unearned revenue	(317,320)	(371,811)
Total net investments in direct financing leases	643,008	666,658
Less current portion	(150,342)	(20,606)
Net investments in direct financing leases	$ 492,666	$ 646,052

Leases and Restricted Cash - 65

Leases and Restricted Cash - Operating Leases - Additional Information (Detail) - Property Subject to Operating Lease $ in Millions	Dec. 31, 2016USD ($)
Operating Leased Assets [Line Items]
Minimum scheduled future revenues, operating lease, 2017	$ 349.2
Minimum scheduled future revenues, operating lease, 2018	372.2
Minimum scheduled future revenues, operating lease, 2019	404
Minimum scheduled future revenues, operating lease, 2020	393.3
Minimum scheduled future revenues, operating lease, 2021	$ 353.5

Equity Accounted Investments -

Equity Accounted Investments - Investments In and Advances to Equity Accounted Investees (Details) $ in Thousands	Jul. 09, 2014vessel	Dec. 31, 2016USD ($)vessel	Dec. 31, 2016USD ($)lease	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Ownership percentage		100.00%	100.00%
Number of vessels		35,000
Investment in and advances to equity accounted joint ventures | $		$ 1,037,726	$ 1,037,726	$ 883,731
Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		30.00%	30.00%
Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%	50.00%
Exmar LPG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%	50.00%
Angola LNG Carriers
Schedule of Equity Method Investments [Line Items]
Ownership percentage		33.00%	33.00%
Number of vessels		4
RasGas 3 Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		40.00%	40.00%
Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels		15,000
Newbuildings | Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of vessels	6	6	6
Equity Method Investments | Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		30.00%	30.00%
Investment in and advances to equity accounted joint ventures | $		$ 63,933	$ 63,933	0
Equity Method Investments | Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%	50.00%
Investment in and advances to equity accounted joint ventures | $		$ 152,702	$ 152,702	99,886
Equity Method Investments | BG Joint Venture
Schedule of Equity Method Investments [Line Items]
Investment in and advances to equity accounted joint ventures | $		$ 33,860	$ 33,860	25,574
Equity Method Investments | Exmar LPG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%	50.00%
Number of vessels		19,000
Investment in and advances to equity accounted joint ventures | $		$ 167,763	$ 167,763	166,430
Equity Method Investments | Teekay LNG-Marubeni Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		52.00%	52.00%
Number of vessels		6,000
Investment in and advances to equity accounted joint ventures | $		$ 299,601	$ 299,601	294,433
Equity Method Investments | Excalibur and Excelsior
Schedule of Equity Method Investments [Line Items]
Number of vessels		2,000
Investment in and advances to equity accounted joint ventures | $		$ 79,577	$ 79,577	77,845
Equity Method Investments | Angola LNG Carriers
Schedule of Equity Method Investments [Line Items]
Ownership percentage		33.00%	33.00%
Number of vessels		4,000
Investment in and advances to equity accounted joint ventures | $		$ 65,644	$ 65,644	58,170
Equity Method Investments | RasGas 3 Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		40.00%	40.00%
Number of vessels		4,000
Investment in and advances to equity accounted joint ventures | $		$ 174,646	$ 174,646	$ 161,393
Equity Method Investments | Newbuildings | Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of vessels		1,000
Equity Method Investments | Newbuildings | Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of vessels		6,000
Equity Method Investments | Newbuildings | BG Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of vessels		4,000
Equity Method Investments | Newbuildings | Exmar LPG Joint Venture
Schedule of Equity Method Investments [Line Items]
Number of vessels		4,000
Equity Method Investments | Minimum | BG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		20.00%	20.00%
Equity Method Investments | Minimum | Excalibur and Excelsior
Schedule of Equity Method Investments [Line Items]
Ownership percentage		49.00%	49.00%
Equity Method Investments | Maximum | BG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage		30.00%	30.00%
Equity Method Investments | Maximum | Excalibur and Excelsior
Schedule of Equity Method Investments [Line Items]
Ownership percentage		50.00%	50.00%

Equity Accounted Investments 67

Equity Accounted Investments - Bahrain LNG Joint Venture - Additional Information (Detail)	Dec. 02, 2015vesselft³	Dec. 31, 2016USD ($)vesselft³	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Number of vessels		35,000
Investment in and advances to equity accounted joint ventures | $		$ 1,037,726,000	$ 883,731,000
Maximum
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage		2.80%
Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels		15,000
Newbuildings | Liquefied Natural Gas
Schedule of Equity Method Investments [Line Items]
Number of vessels		9
Newbuildings | Daewoo Shipbuilding & Marine Engineering Co. Ltd. | Liquefied Natural Gas
Schedule of Equity Method Investments [Line Items]
Number of vessels	9
Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Partnership owns percentage in joint venture	30.00%
Advances to equity accounted joint ventures | $		$ 62,900,000	0
Accrued investment income receivable | $		$ 100,000	$ 0
Bahrain LNG Joint Venture | Daewoo Shipbuilding & Marine Engineering Co. Ltd. | Modified Vessel
Schedule of Equity Method Investments [Line Items]
Length of charter contract	20 years
Bahrain LNG Joint Venture | LNG Receiving and Regasification Terminal
Schedule of Equity Method Investments [Line Items]
Capacity of production facility, per day (in cubic feet) | ft³		800,000,000
Length of charter contract	20 years	20 years
Bahrain LNG Joint Venture | LNG Receiving and Regasification Terminal | Maximum
Schedule of Equity Method Investments [Line Items]
Capacity of production facility, per day (in cubic feet) | ft³	800,000,000
Bahrain LNG Joint Venture | Nogaholding
Schedule of Equity Method Investments [Line Items]
Partnership owns percentage in joint venture	30.00%
Bahrain LNG Joint Venture | Gic
Schedule of Equity Method Investments [Line Items]
Partnership owns percentage in joint venture	24.00%
Bahrain LNG Joint Venture | Samsung
Schedule of Equity Method Investments [Line Items]
Partnership owns percentage in joint venture	16.00%
LIBOR | Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage		1.25%

Equity Accounted Investments 68

Equity Accounted Investments - Yamal LNG Joint Venture - Additional Information (Detail) $ in Thousands	Jul. 09, 2014vessel	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)vessel	Dec. 31, 2016USD ($)lease	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Joint venture ownership percentage		100.00%	100.00%	100.00%
Number of vessels | vessel			35,000
Investment in and advances to equity accounted joint ventures		$ 1,037,726	$ 1,037,726	$ 1,037,726	$ 883,731
Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels | vessel			15,000
Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Joint venture ownership percentage		50.00%	50.00%	50.00%
Advances to equity accounted joint ventures		$ 146,700	$ 146,700	$ 146,700	96,900
Accrued investment income receivable		$ 9,400	$ 9,400	$ 9,400	$ 4,800
Yamal LNG Joint Venture | Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels	6		6	6
Yamal LNG Joint Venture | China LNG
Schedule of Equity Method Investments [Line Items]
Joint venture ownership percentage	50.00%
LIBOR | Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage		3.00%

Equity Accounted Investments 69

Equity Accounted Investments - BG Joint Venture - Additional Information (Detail) m³ in Thousands	Jun. 27, 2014USD ($)vesselm³	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)vessel	Dec. 31, 2016USD ($)lease	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Schedule of Equity Method Investments [Line Items]
Number of vessels | vessel			35,000
Ownership percentage		100.00%	100.00%	100.00%
Value of service obligation		$ 8,233,000	$ 8,233,000	$ 8,233,000	$ 20,065,000
Drawings from long-term debt facility		573,514,000			391,574,000	$ 944,123,000
Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels | vessel			15,000
Shipbuilding supervision and crew training services | Newbuildings | Fair Value Asset (Liability)
Schedule of Equity Method Investments [Line Items]
Value of service obligation						33,300,000
BG Joint Venture
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount and book value		16,800,000	$ 16,800,000	16,800,000	16,800,000
Drawings from long-term debt facility		221,000,000			110,300,000
Debt facility used to finance a portion of estimated fully built-up cost		787,000,000	$ 787,000,000	$ 787,000,000
Capital contributions received from the Partnership		16,600,000			8,600,000
BG Joint Venture | Shipbuilding supervision and crew training services | Newbuildings
Schedule of Equity Method Investments [Line Items]
Number of vessels	4		4	4
Volume of vessels (in cubic meter) | m³	174
Fully built-up cost	$ 1,000,000,000
Value of service obligation	36,900,000	22,600,000	$ 22,600,000	$ 22,600,000	29,700,000
Amounts due	20,300,000	$ 10,900,000	$ 10,900,000	$ 10,900,000	$ 16,500,000	$ 20,300,000
BG Joint Venture | Shipbuilding supervision and crew training services | Newbuildings | Fair Value Asset (Liability)
Schedule of Equity Method Investments [Line Items]
Value of service obligation	33,300,000
Amounts due	$ 16,500,000
BG Joint Venture | Shipbuilding supervision and crew training services | Newbuildings | 30% Ownership
Schedule of Equity Method Investments [Line Items]
Number of vessels | vessel	2
Ownership percentage	30.00%
BG Joint Venture | Shipbuilding supervision and crew training services | Newbuildings | 20% Ownership
Schedule of Equity Method Investments [Line Items]
Number of vessels | vessel	2
Ownership percentage	20.00%

Equity Accounted Investments 70

Equity Accounted Investments - Exmar LPG Joint Venture - Additional Information (Detail) - USD ($)	1 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Investment in and advances to equity accounted joint ventures		$ 1,037,726,000	$ 883,731,000
Exmar LPG Joint Venture
Schedule of Equity Method Investments [Line Items]
Carrying value of guarantee liability	$ 1,700,000	1,300,000	1,500,000
Advances to equity accounted joint ventures		52,300,000	57,800,000
Accrued investment income receivable		1,100,000	400,000
Difference between carrying amount and book value		$ 30,200,000	$ 36,400,000
Exmar LPG Joint Venture | LIBOR
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage		0.50%
Exmar LPG Joint Venture | Maturing In 2021
Schedule of Equity Method Investments [Line Items]
Long-term debt facility	$ 460,000,000
Parent guarantee percent	50.00%
Exmar LPG Joint Venture | Maturing In 2021 | LIBOR
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage	1.90%

Equity Accounted Investments 71

Equity Accounted Investments - Teekay LNG-Marubeni Joint Venture - Additional Information (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Jul. 31, 2013
Schedule of Equity Method Investments [Line Items]
Refinancing of its short-term loan facilities by entering into long-term debt facilities	$ 1,791,226	$ 1,999,209
Teekay LNG-Marubeni Joint Venture
Schedule of Equity Method Investments [Line Items]
Refinancing of its short-term loan facilities by entering into long-term debt facilities	396,000		$ 963,000
Parent guarantee percent			52.00%
Teekay LNG-Marubeni Joint Venture | Teekay Lng
Schedule of Equity Method Investments [Line Items]
Carrying value of guarantee liability	$ 100	$ 200	$ 700

Equity Accounted Investments 72

Equity Accounted Investments - Excalibur and Excelsior Joint Ventures - Additional Information (Detail) - USD ($) $ in Thousands	1 Months Ended
	Feb. 28, 2015	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Total principal		$ 1,804,483	$ 2,015,472
Excalibur and Excelsior
Schedule of Equity Method Investments [Line Items]
Carrying value of guarantee liability	$ 400	200	300
Ne assets		$ 37,200	$ 38,600
Excalibur and Excelsior | Maturing In 2019
Schedule of Equity Method Investments [Line Items]
Total principal	$ 172,800
Parent guarantee percent	50.00%
Excalibur and Excelsior | Maturing In 2019 | LIBOR
Schedule of Equity Method Investments [Line Items]
Interest bearing percentage	2.75%

Equity Accounted Investments 73

Equity Accounted Investments - Angola Joint Venture - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016vesselm³
Schedule of Equity Method Investments [Line Items]
Percentage of ownership in joint venture	100.00%
Number of vessels	35,000
Angola LNG Carriers
Schedule of Equity Method Investments [Line Items]
Percentage of ownership in joint venture	33.00%
Number of vessels	4
Volume of vessels (in cubic meter) | m³	160,400
NYK Energy Transport
Schedule of Equity Method Investments [Line Items]
Percentage of ownership in joint venture	33.00%
Mitsui & Co. Ltd
Schedule of Equity Method Investments [Line Items]
Percentage of ownership in joint venture	34.00%

Equity Accounted Investments 74

Equity Accounted Investments - RasGas 3 Joint Venture - Additional Information (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 21, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Ownership percentage	100.00%
Investment in and advances to equity accounted joint ventures	$ 1,037,726		$ 883,731
Long-term debt	$ 1,791,226		1,999,209
RasGas 3 Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage	40.00%
Long-term debt		$ 610,000
RasGas 3 Joint Venture | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Ownership percentage	40.00%
Investment in and advances to equity accounted joint ventures	$ 174,646		161,393
Qatar Gas Transport Company Ltd
Schedule of Equity Method Investments [Line Items]
Ownership percentage	60.00%
Excelsior Joint Venture
Schedule of Equity Method Investments [Line Items]
Long-term debt	$ 45,000
Excelsior Joint Venture | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Investment in and advances to equity accounted joint ventures	$ 50,300
Angola LNG Carriers
Schedule of Equity Method Investments [Line Items]
Ownership percentage	33.00%
Long-term debt	$ 256,100
Carrying value of guarantee liability	$ 1,000		1,200
Angola LNG Carriers | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Ownership percentage	33.00%
Investment in and advances to equity accounted joint ventures	$ 65,644		58,170
Yamal LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Yamal LNG Joint Venture | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Investment in and advances to equity accounted joint ventures	$ 152,702		99,886
Bahrain LNG Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership percentage	30.00%
Bahrain LNG Joint Venture | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Ownership percentage	30.00%
Investment in and advances to equity accounted joint ventures	$ 63,933		$ 0

Equity Accounted Investments 75

Equity Accounted Investments - Financial Information of Joint Ventures (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Vessels and equipment	$ 2,215,983	$ 2,108,160
Net investments in direct financing leases – non-current	643,008	666,658
Other assets – non-current	5,529	20,811
Other liabilities – non-current	60,573	71,152
Voyage revenues	396,444	397,991	$ 402,928
Income from vessel operations	153,181	181,372	183,823
Realized and unrealized loss on non-designated derivative instruments	(7,161)	(20,022)	(44,682)
Net income	157,965	217,510	218,927
Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Cash and cash equivalents and restricted cash	388,007	281,943
Other assets – current	111,847	77,861
Vessels and equipment	2,837,870	2,343,397
Net investments in direct financing leases – non-current	1,776,954	1,813,991
Other assets – non-current	37,132	22,120
Current portion of long-term debt and obligations under capital lease	209,814	166,522
Other liabilities – current	102,385	97,405
Long-term debt and obligations under capital lease	3,233,425	2,787,055
Other liabilities – non-current	157,025	177,879
Voyage revenues	549,646	596,093	640,105
Income from vessel operations	268,049	302,731	398,836
Realized and unrealized loss on non-designated derivative instruments	(12,277)	(25,108)	(52,938)
Net income	$ 167,052	$ 203,280	$ 267,990

Intangible Assets and Goodwil76

Intangible Assets and Goodwill - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Weighted-average amortization period of intangible assets consisted of time-charter contracts	20 years 8 months 12 days	20 years 8 months 12 days
Amortization of intangible assets	$ 8,900,000	$ 8,900,000	$ 9,200,000
Amortization expense of intangible assets, 2017	8,900,000
Amortization expense of intangible assets, 2018	8,900,000
Amortization expense of intangible assets, 2019	8,900,000
Amortization expense of intangible assets, 2020	8,900,000
Amortization expense of intangible assets, 2021	8,900,000
Carrying amount of goodwill	35,631,000	35,631,000
Goodwill impairment	$ 0	$ 0

Intangible Assets and Goodwil77

Intangible Assets and Goodwill - Carrying Amount of Intangible Assets for Partnership's Reportable Segments (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Net carrying amount	$ 69,934	$ 78,790
Liquefied Gas Segment
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	179,813	179,813
Accumulated amortization	(109,879)	(101,023)
Net carrying amount	$ 69,934	$ 78,790

Accrued Liabilities (Detail)

Accrued Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Payables and Accruals [Abstract]
Interest including interest rate swaps	$ 19,957	$ 17,484
Voyage and vessel expenses	9,311	9,315
Payroll and benefits	3,355	5,431
Other general expenses	3,069	2,785
Income tax payable and other	189	2,441
Total	$ 35,881	$ 37,456

Long-Term Debt - Components of

Long-Term Debt - Components of Long-Term Debt (Detail) $ in Thousands, € in Millions	Dec. 31, 2016USD ($)	Dec. 31, 2016EUR (€)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Total principal	$ 1,804,483		$ 2,015,472
Unamortized discount and debt issuance costs	(13,257)		(16,263)
Total debt	1,791,226		1,999,209
Less current portion	(188,511)		(197,197)
Long-term debt	1,602,715		1,802,012
U.S. Dollar-denominated Revolving Credit Facilities due from 2017 to 2018
Debt Instrument [Line Items]
Total principal	208,222		329,222
U.S. Dollar-denominated Term Loans due from 2018 to 2026
Debt Instrument [Line Items]
Total principal	1,005,199		1,150,436
Total debt	1,000,000
Norwegian Kroner-denominated Bonds due from 2017 to 2021
Debt Instrument [Line Items]
Total principal	371,329		294,016
Euro-denominated Term Loans due from 2018 to 2023
Debt Instrument [Line Items]
Total principal	219,733		$ 241,798
Total debt	$ 219,700	€ 208.9

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information - Revolvers (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)vesselcredit_facility	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Number of vessels | vessel	35,000
Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Revolving Credit Facility
Debt Instrument [Line Items]
Number of credit facilities	3
Borrowings provided under revolving credit facilities | $	$ 451.9	$ 459.2
Undrawn amount of revolving credit facilities | $	243.7	$ 130
Reduction in 2017 | $	198.2
Reduction in 2018 | $	$ 253.7
Months required to repay all borrowings	P12M
Revolving Credit Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.55%
Revolving Credit Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	1.25%
Line of Credit
Debt Instrument [Line Items]
Number of credit facilities	2
Unsecured Debt
Debt Instrument [Line Items]
Number of credit facilities	1
Collateralized Mortgage Backed Securities
Debt Instrument [Line Items]
Number of credit facilities	2
Number of vessels | vessel	4
Line of Credit
Debt Instrument [Line Items]
Number of credit facilities	1

Long-Term Debt - Additional I81

Long-Term Debt - Additional Information - USD Term Loans (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)vesselterm_loan	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Number of term loans | term_loan	6
Outstanding debt | $	$ 1,791,226	$ 1,999,209
Number of vessels	35,000
Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Teekay Nakilat Corporation
Debt Instrument [Line Items]
Number of vessels	3
Partnership owns percentage in joint venture	70.00%
Long-term Debt
Debt Instrument [Line Items]
Outstanding debt | $	$ 1,000,000
Number of vessels	15
Long-term Debt | Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Long-term Debt | LIBOR | Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Norwegian Kroner Denominated Bonds Due September 2018
Debt Instrument [Line Items]
Reference rate for the variable rate of the debt instrument	all of the outstanding term loans were guaranteed by either the Partnership or Teekay Nakilat Corporation (or the Teekay Nakilat Joint Venture)

Long-Term Debt - Additional I82

Long-Term Debt - Additional Information - NOK Bonds (Detail) $ in Thousands, NOK in Billions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2016NOK	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Senior unsecured bonds issued | NOK		NOK 3.2
Carrying amount of bonds	$ 1,804,483		$ 2,015,472
Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Unsecured Debt
Debt Instrument [Line Items]
Senior unsecured bonds issued | NOK		NOK 3.5
Carrying amount of bonds	$ 371,329		$ 294,016
Unsecured Debt | Foreign Exchange Contract
Debt Instrument [Line Items]
Transfer of principal amount	$ 467,000
Unsecured Debt | Minimum | Foreign Exchange Contract
Debt Instrument [Line Items]
Fixed interest rate	5.92%	5.92%
Unsecured Debt | Maximum | Foreign Exchange Contract
Debt Instrument [Line Items]
Fixed interest rate	7.72%	7.72%
Unsecured Debt | NIBOR | Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	3.70%
Unsecured Debt | NIBOR | Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	6.00%

Long-Term Debt - Euro-denominat

Long-Term Debt - Euro-denominated term loans- Additional Information (Detail) $ in Thousands, € in Millions	12 Months Ended
	Dec. 31, 2016USD ($)vesselsubsidiarycredit_facility	Dec. 31, 2016EUR (€)credit_facility	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Outstanding debt | $	$ 1,791,226		$ 1,999,209
Number of vessels	35,000
Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Euro Denominated Term Loans
Debt Instrument [Line Items]
Number of credit facilities | credit_facility	2	2
Outstanding debt	$ 219,700	€ 208.9
Reference rate for the variable rate of the debt instrument	EURIBOR
Number of vessels	2
Number of subsidiaries | subsidiary	1
Euro Denominated Term Loans | EURIBOR | Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.60%
Euro Denominated Term Loans | EURIBOR | Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.25%

Long-Term Debt - Additional I84

Long-Term Debt - Additional Information - Other (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)credit_facility	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Weighted-average interest rate for the Partnership's long-term debt outstanding	3.03%	2.33%
Foreign exchange (losses) gains	$ 5,335	$ 13,943	$ 28,401
Aggregate annual long-term debt principal repayments, 2017	190,100
Aggregate annual long-term debt principal repayments, 2018	719,800
Aggregate annual long-term debt principal repayments, 2019	82,500
Aggregate annual long-term debt principal repayments, 2020	178,000
Aggregate annual long-term debt principal repayments, 2021	288,400
Aggregate annual long-term debt principal repayments,thereafter	345,700
Long-term debt	1,791,226	$ 1,999,209
Notes Payable to Banks
Debt Instrument [Line Items]
Long-term debt	$ 127,800
Number of credit facilities | credit_facility	2
Minimum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	0.30%
Percentage of vessel value to outstanding loan principal balance	110.00%
Minimum | Vessel
Debt Instrument [Line Items]
Percentage of vessel value to outstanding loan principal balance	133.00%
Maximum
Debt Instrument [Line Items]
Marginal rate added to LIBOR and NIBOR for interest paid on first tranche under the loan facility	2.80%
Percentage of vessel value to outstanding loan principal balance	115.00%
Maximum | Vessel
Debt Instrument [Line Items]
Percentage of vessel value to outstanding loan principal balance	209.00%

Income Tax - Components of Prov

Income Tax - Components of Provision for Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Current	$ (962)	$ (2,646)	$ (5,212)
Deferred	(11)	(76)	(2,355)
Income tax expense	$ (973)	$ (2,722)	$ (7,567)

Income Tax - Reconciliations of

Income Tax - Reconciliations of Tax Charge (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Net income before income tax expense	$ 158,938	$ 220,232	$ 226,494
Net income not subject to taxes	(138,542)	(173,298)	(81,604)
Net income subject to taxes	20,396	46,934	144,890
At applicable statutory tax rates
Amount computed using the standard rate of corporate tax	(3,338)	(12,007)	(33,083)
Adjustments to valuation allowance and uncertain tax positions	11,802	5,362	14,851
Permanent and currency differences	(9,125)	4,204	11,507
Change in tax rate	(312)	(281)	(842)
Income tax expense	$ (973)	$ (2,722)	$ (7,567)

Income Tax - Components of Part

Income Tax - Components of Partnership's Deferred Tax Assets (Liabilities) (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Derivative instruments	$ 4,523	$ 7,021
Taxation loss carryforwards and disallowed finance costs	34,927	44,823
Vessels and equipment	3,554	3,462
Capitalized interest	(2,027)	(2,184)
Gross deferred tax assets	40,977	53,122
Valuation allowance	(41,064)	(53,198)
Net deferred tax liabilities included in accrued liabilities	$ (87)	$ (76)

Income Tax - Additional Informa

Income Tax - Additional Information (Detail) € in Millions, $ in Millions	Dec. 31, 2016USD ($)	Dec. 31, 2016EUR (€)	Dec. 31, 2015USD ($)	Dec. 31, 2015EUR (€)
United Kingdom
Operating Loss Carryforwards [Line Items]
Taxation loss carryforwards	$ 12.7		$ 12.7
Spain
Operating Loss Carryforwards [Line Items]
Taxation loss carryforwards	116.1	€ 110.3	119.8	€ 110.3
Disallowed costs carried forward	36.4	34.6	37.2	34.2
Luxembourg
Operating Loss Carryforwards [Line Items]
Taxation loss carryforwards	$ 98.1	€ 93.3	131.3	120.9
Tax Authority, Spain | Spain
Operating Loss Carryforwards [Line Items]
Taxation loss carryforwards			$ 30.5	€ 29

Related Party Transactions - Ar

Related Party Transactions - Arctic Spirit and Polar Spirit - Additional Information (Detail)	Jun. 27, 2014vessel	Dec. 31, 2016vessel	Dec. 31, 2016lease
Related Party Transaction [Line Items]
Number of vessels		35,000
Newbuildings
Related Party Transaction [Line Items]
Number of vessels		15,000
Newbuildings | BG Joint Venture | Shipbuilding supervision and crew training services
Related Party Transaction [Line Items]
Number of vessels	4	4	4
Liquefied Natural Gas | Newbuildings
Related Party Transaction [Line Items]
Number of vessels		9
Subsidiary of Common Parent | Liquefied Natural Gas | Charters-out
Related Party Transaction [Line Items]
Number of vessels		2

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Voyage revenues	$ 396,444	$ 397,991	$ 402,928
General and administrative expenses	(18,499)	(25,118)	(23,860)
Affiliated Entity
Related Party Transaction [Line Items]
Voyage revenues	37,336	35,887	37,596
Vessel operating expenses	(20,438)	(19,914)	(12,703)
General and administrative expenses	(11,890)	(14,485)	(13,708)
Deferred and Capitalized Expenses | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses	$ (571)	$ 0	$ 0

Related Party Transactions - 91

Related Party Transactions - Schedule of Related Party Transactions - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
General and administrative expenses deferred and capitalized	$ 18,499	$ 25,118	$ 23,860
Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses deferred and capitalized	$ 11,890	14,485	13,708
Teekay Corporation | Affiliated Entity
Related Party Transaction [Line Items]
Operating lease arrangement period, lessor	10 years
Teekay Corporation | Affiliated Entity | Maximum
Related Party Transaction [Line Items]
Additional time period for fixed-rate time-charters contract	15 years
Deferred and Capitalized Expenses | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses deferred and capitalized	$ 571	$ 0	$ 0
Deferred and Capitalized Expenses | Bahrain LNG Joint Venture
Related Party Transaction [Line Items]
General and administrative expenses deferred and capitalized	$ 400

Related Party Transactions - Sk

Related Party Transactions - Skaugen - Additional Information (Detail) $ in Thousands	Nov. 13, 2014USD ($)m³	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Acquisition cost of vessels and associated fixed-rate contracts		$ 344,987	$ 191,969	$ 194,255
Sale price of interest sold in Norgas Napa				216
Skaugen
Related Party Transaction [Line Items]
Volume of vessels (in cubic meter) | m³	10,200
Acquisition cost of vessels and associated fixed-rate contracts	$ 27,000			$ 27,000
Operating lease arrangement period, lessor	5 years
Skaugen | Teekay Corporation
Related Party Transaction [Line Items]
Percentage interest sold in Norgas Napa	1.00%
Sale price of interest sold in Norgas Napa	$ 200

Related Party Transactions - In

Related Party Transactions - Interest Rate Swap Agreements - Additional Information (Detail) $ in Thousands	1 Months Ended	12 Months Ended
	Mar. 31, 2014USD ($)agreement	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Novation of derivative liabilities		$ 0	$ 0	$ 2,985
Teekay Corporation | Affiliated Entity
Related Party Transaction [Line Items]
Number of interest rate swap agreements | agreement	2
Novation of derivative liabilities	$ 3,000

Related Party Transactions - Sh

Related Party Transactions - Shipbuilding and Site Supervision Services Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)vessel	Dec. 31, 2015USD ($)vessel	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Number of vessels	35,000
Aggregate shipbuilding and site supervision costs | $	$ 357,602	$ 424,868
Newbuildings
Related Party Transaction [Line Items]
Number of vessels	15,000
Liquefied Natural Gas | Newbuildings
Related Party Transaction [Line Items]
Number of vessels	9
Affiliated Entity | Liquefied Natural Gas | Newbuildings
Related Party Transaction [Line Items]
Number of vessels	9	11
Shipbuilding and site supervision costs | $	$ 8,500	$ 4,300	$ 3,100
Affiliated Entity | Liquefied Natural Gas | Newbuildings | Teekay Corporation Subsidiaries
Related Party Transaction [Line Items]
Aggregate shipbuilding and site supervision costs | $	$ 10,100	$ 7,600

Related Party Transactions - No

Related Party Transactions - Non-interest Bearing Advances - Additional Information (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Advances to affiliates	$ 9,739	$ 13,026
Advances from affiliates	15,492	22,987
Affiliated Entity
Related Party Transaction [Line Items]
Advances to affiliates	9,700	13,000
Advances from affiliates	$ 15,500	$ 23,000

Derivative Instruments and He96

Derivative Instruments and Hedging Activities - Additional Information (Detail) $ in Thousands, NOK in Billions	Dec. 31, 2016USD ($)	Dec. 31, 2016NOK	Dec. 31, 2015USD ($)agreement
Derivative [Line Items]
Senior unsecured bonds issued | NOK		NOK 3.2
Restricted cash - current and - long-term	$ 117,000		$ 111,500
Interest rate swaption agreements
Derivative [Line Items]
Number of interest rate derivatives held | agreement			3
Interest Rate Swaps And Swaptions And Cross Currency Swaps Agreement
Derivative [Line Items]
Fair value, asset	4,200
Fair value, liability	173,600
Restricted cash - current and - long-term	37,800		$ 44,800
Toledo Spirit time-charter derivative
Derivative [Line Items]
Derivative fair value, net	(2,100)		6,300
Unsecured Debt
Derivative [Line Items]
Senior unsecured bonds issued | NOK		NOK 3.5
Recurring | Reported Value Measurement | Level 3
Derivative [Line Items]
Derivative fair value, net	2,134		(6,296)
Recurring | Fair Value Asset (Liability) | Level 3
Derivative [Line Items]
Derivative fair value, net	$ 2,134		$ (6,296)

Derivative Instruments and He97

Derivative Instruments and Hedging Activities - Summary of Cross Currency Swap Agreements (Detail) - Cross-currency swap agreements $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2016NOK
Derivative [Line Items]
Fair Value / Carrying Amount of (Liability)	$ (99,786)
Margin 5.25% | NIBOR
Derivative [Line Items]
Principal Amount	$ 72,946	NOK 408,500,000
Margin	5.25%	5.25%
Fixed Rate Payable	6.88%	6.88%
Fair Value / Carrying Amount of (Liability)	$ (26,417)
Weighted- Average Remaining Term (Years)	3 months 18 days
Margin 4.35% | NIBOR
Derivative [Line Items]
Principal Amount	$ 150,000	NOK 900,000,000
Margin	4.35%	4.35%
Fixed Rate Payable	6.43%	6.43%
Fair Value / Carrying Amount of (Liability)	$ (49,655)
Weighted- Average Remaining Term (Years)	1 year 8 months 12 days
Margin 3.70% | NIBOR
Derivative [Line Items]
Principal Amount	$ 134,000	NOK 1,000,000,000
Margin	3.70%	3.70%
Fixed Rate Payable	5.92%	5.92%
Fair Value / Carrying Amount of (Liability)	$ (19,900)
Weighted- Average Remaining Term (Years)	3 years 4 months 24 days
Margin 6.00% | NIBOR
Derivative [Line Items]
Principal Amount	$ 110,400	NOK 900,000,000
Margin	6.00%	6.00%
Fixed Rate Payable	7.72%	7.72%
Fair Value / Carrying Amount of (Liability)	$ (3,814)
Weighted- Average Remaining Term (Years)	4 years 9 months 18 days

Derivative Instruments and He98

Derivative Instruments and Hedging Activities - Interest Rate Swap Agreements (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
United States Dollar-denominated interest rate swaps 1 | LIBOR
Derivative [Line Items]
Principal Amount	$ 90,000
Fair Value /Carrying Amount of Assets (Liability)	$ (5,748)
Weighted- Average Remaining Term (Years)	1 year 8 months 12 days
Fixed Interest Rate (%)	490.00%
United States Dollar-denominated interest rate swaps 2 | LIBOR
Derivative [Line Items]
Principal Amount	$ 100,000
Fair Value /Carrying Amount of Assets (Liability)	$ (1,145)
Weighted- Average Remaining Term (Years)	0 days
Fixed Interest Rate (%)	530.00%
United States Dollar-denominated interest rate swaps 3 | LIBOR
Derivative [Line Items]
Principal Amount	$ 156,250
Fair Value /Carrying Amount of Assets (Liability)	$ (26,765)
Weighted- Average Remaining Term (Years)	12 years
Fixed Interest Rate (%)	520.00%
United States Dollar-denominated interest rate swaps 4 | LIBOR
Derivative [Line Items]
Principal Amount	$ 53,557
Fair Value /Carrying Amount of Assets (Liability)	$ (1,494)
Weighted- Average Remaining Term (Years)	4 years 7 months 6 days
Fixed Interest Rate (%)	280.00%
United States Dollar-denominated interest rate swaps 5 | LIBOR
Derivative [Line Items]
Principal Amount	$ 320,000
Fair Value /Carrying Amount of Assets (Liability)	$ (17,079)
Weighted- Average Remaining Term (Years)	1 year
Fixed Interest Rate (%)	340.00%
United States Dollar-denominated interest rate swaps 6 | LIBOR
Derivative [Line Items]
Principal Amount	$ 108,333
Fair Value /Carrying Amount of Assets (Liability)	$ (665)
Weighted- Average Remaining Term (Years)	2 years
Fixed Interest Rate (%)	170.00%
United States Dollar-denominated interest rate swaps 7 | LIBOR
Derivative [Line Items]
Principal Amount	$ 197,629
Fair Value / Carrying Amount of Assets (Liability)	$ 590
Weighted- Average Remaining Term (Years)	9 years 2 months 12 days
Fixed Interest Rate (%)	230.00%
Euro-denominated interest rate swaps | EURIBOR
Derivative [Line Items]
Principal Amount	$ 219,733
Fair Value /Carrying Amount of Assets (Liability)	$ (34,295)
Weighted- Average Remaining Term (Years)	4 years
Fixed Interest Rate (%)	310.00%
Interest rate swap agreements
Derivative [Line Items]
Interest rate swap agreements – liabilities	$ (86,601)

Derivative Instruments and He99

Derivative Instruments and Hedging Activities - Interest Rate Swap Agreements (Footnotes) (Detail) - 12 months ended Dec. 31, 2016 € in Millions, $ in Millions	USD ($)	EUR (€)
Derivative [Line Items]
Reducing principal amount of interest rate swaps	$ 73.7	€ 70.1
Minimum
Derivative [Line Items]
Interest bearing percentage	0.30%
Maximum
Derivative [Line Items]
Interest bearing percentage	2.80%

Derivative Instruments and H100

Derivative Instruments and Hedging Activities - Terms of Interest Rate Swaps Underlying Swaption (Detail) - Interest rate swaption agreements - LIBOR	12 Months Ended
	Dec. 31, 2016USD ($)
Call Option | April 28, 2017
Derivative [Line Items]
Principal Amount	$ 155,000,000
Option Exercise Date	Apr. 28, 2017
Fair Value / Carrying Amount of Assets (Liability)	$ 31,000
Remaining Term (Years)	7 years 6 months
Fixed Interest Rate (%)	330.00%
Call Option | January 31, 2018
Derivative [Line Items]
Principal Amount	$ 160,000,000
Option Exercise Date	Jan. 31, 2018
Fair Value / Carrying Amount of Assets (Liability)	$ 1,140,000
Remaining Term (Years)	8 years
Fixed Interest Rate (%)	310.00%
Call Option | July 16, 2018
Derivative [Line Items]
Principal Amount	$ 160,000,000
Option Exercise Date	Jul. 16, 2018
Fair Value / Carrying Amount of Assets (Liability)	$ 2,112,000
Remaining Term (Years)	8 years
Fixed Interest Rate (%)	290.00%
Put Option | April 28, 2017
Derivative [Line Items]
Principal Amount	$ 155,000,000
Option Exercise Date	Apr. 28, 2017
Fair Value / Carrying Amount of Assets (Liability)	$ (1,525,000)
Remaining Term (Years)	7 years 6 months
Fixed Interest Rate (%)	220.00%
Put Option | January 31, 2018
Derivative [Line Items]
Principal Amount	$ 160,000,000
Option Exercise Date	Jan. 31, 2018
Fair Value / Carrying Amount of Assets (Liability)	$ (1,457,000)
Remaining Term (Years)	8 years
Fixed Interest Rate (%)	200.00%
Put Option | July 16, 2018
Derivative [Line Items]
Principal Amount	$ 160,000,000
Option Exercise Date	Jul. 16, 2018
Fair Value / Carrying Amount of Assets (Liability)	$ (1,248,000)
Remaining Term (Years)	8 years
Fixed Interest Rate (%)	180.00%

Derivative Instruments and H101

Derivative Instruments and Hedging Activities - Terms of Interest Rate Swaps Underlying Swaption (Footnotes) (Detail) - USD ($) $ in Millions	Jul. 31, 2026	Jan. 31, 2026	Oct. 31, 2024	Jul. 31, 2018	Jan. 31, 2018	Apr. 30, 2017
Interest rate swaption agreements | Forecast
Derivative [Line Items]
Principal Amount	$ 82.5	$ 82.5	$ 85.4	$ 160	$ 160	$ 155

Derivative Instruments and H102

Derivative Instruments and Hedging Activities - Location and Fair Value Amounts of Derivative Instruments (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Advances to affiliates	$ 9,739	$ 13,026
Current portion of derivative assets	531	0
Derivative assets	4,692	5,623
Current portion of derivative liabilities	(56,800)	(52,083)
Derivative liabilities	(128,293)	(182,338)
Interest rate swap agreements
Derivatives, Fair Value [Line Items]
Advances to affiliates	0	0
Current portion of derivative assets	0	0
Derivative assets	1,080	0
Accrued liabilities/ Advances from affiliates	(5,514)	(6,833)
Current portion of derivative liabilities	(22,432)	(41,028)
Derivative liabilities	(59,735)	(56,276)
Interest rate swaption agreements
Derivatives, Fair Value [Line Items]
Advances to affiliates	0	0
Current portion of derivative assets	31	0
Derivative assets	3,252	5,623
Accrued liabilities/ Advances from affiliates	0	0
Current portion of derivative liabilities	(1,525)	0
Derivative liabilities	(2,705)	(6,406)
Cross-currency swap agreements
Derivatives, Fair Value [Line Items]
Advances to affiliates	0	0
Current portion of derivative assets	0	0
Derivative assets	0	0
Accrued liabilities/ Advances from affiliates	(1,090)	(1,181)
Current portion of derivative liabilities	(32,843)	(9,755)
Derivative liabilities	(65,853)	(117,846)
Toledo Spirit time-charter derivative
Derivatives, Fair Value [Line Items]
Advances to affiliates	1,274	0
Current portion of derivative assets	500	0
Derivative assets	360	0
Accrued liabilities/ Advances from affiliates	0	(3,186)
Current portion of derivative liabilities	0	(1,300)
Derivative liabilities	0	(1,810)
Derivative
Derivatives, Fair Value [Line Items]
Advances to affiliates	1,274	0
Current portion of derivative assets	531	0
Derivative assets	4,692	5,623
Accrued liabilities/ Advances from affiliates	(6,604)	(11,200)
Current portion of derivative liabilities	(56,800)	(52,083)
Derivative liabilities	$ (128,293)	$ (182,338)

Derivative Instruments and H103

Derivative Instruments and Hedging Activities - Gain (Loss) for Derivative Instruments Not Designated or Qualifying as Hedging Instruments (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized gains (losses)	$ (26,594)	$ (32,397)	$ (42,586)
Unrealized gains (losses)	19,433	12,375	(2,096)
Total	(7,161)	(20,022)	(44,682)
Unrealized gains (losses)	42,009	26,090	24,931
Interest rate swap agreements
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized gains (losses)	(25,940)	(28,968)	(39,406)
Unrealized gains (losses)	15,627	14,768	4,204
Total	(10,313)	(14,200)	(35,202)
Interest rate swaption agreements
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized gains (losses)	0	0	0
Unrealized gains (losses)	(164)	(783)	0
Total	(164)	(783)	0
Interest rate swap agreements termination
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized gains (losses)	0	0	(2,319)
Unrealized gains (losses)	0	0	0
Total	0	0	(2,319)
Toledo Spirit time-charter derivative
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized gains (losses)	(654)	(3,429)	(861)
Unrealized gains (losses)	3,970	(1,610)	(6,300)
Total	3,316	(5,039)	(7,161)
Cross-currency swap agreements | Foreign Currency Gain (Loss) [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total	19,842	(65,399)	(53,984)
Realized gains (losses)	(9,063)	(7,640)	(2,222)
Unrealized gains (losses)	28,905	(57,759)	(51,762)
Cross-currency swap agreements termination | Foreign Currency Gain (Loss) [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total	(17,711)	0	0
Realized gains (losses)	(17,711)	0	0
Unrealized gains (losses)	0	0	0
Cross-currency swap agreements | Foreign Currency Gain (Loss) [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total	2,131	(65,399)	(53,984)
Realized gains (losses)	(26,774)	(7,640)	(2,222)
Unrealized gains (losses)	$ 28,905	$ (57,759)	$ (51,762)

Derivative Instruments and H104

Derivative Instruments and Hedging Activities - Effective Portion of Gains (Losses) on Interest Rate Swap Agreements (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Derivative [Line Items]
Effective Portion Recognized in AOCI	$ 590
Effective Portion Reclassified from AOCI	0
Ineffective Portion	0
Interest Expense
Derivative [Line Items]
Effective Portion Recognized in AOCI	590
Effective Portion Reclassified from AOCI	0
Ineffective Portion	$ 0

Commitments and Contingencies -

Commitments and Contingencies - Commitments to Fund Newbuilding and Other Construction Contract Costs (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	$ 2,876,871
2,017	1,049,958
2,018	1,067,206
2,019	561,127
2,020	198,580
Yamal LNG Joint Venture
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	883,030
2,017	91,800
2,018	344,850
2,019	247,800
2,020	198,580
BG Joint Venture
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	195,565
2,017	80,010
2,018	86,154
2,019	29,401
2,020	0
Bahrain LNG Joint Venture
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	224,080
2,017	110,364
2,018	80,097
2,019	33,619
2,020	0
Exmar LPG Joint Venture
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	77,504
2,017	58,096
2,018	19,408
2,019	0
2,020	0
DSME
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	1,118,345
2,017	627,181
2,018	491,164
2,019	0
2,020	0
Hyundai Samho Heavy Industries Co Ltd
Unrecorded Unconditional Purchase Obligation [Line Items]
Total	378,347
2,017	82,507
2,018	45,533
2,019	250,307
2,020	$ 0

Commitments and Contingencie106

Commitments and Contingencies - Additional Information (Detail) m³ in Thousands, $ in Thousands	Apr. 21, 2017USD ($)building	Dec. 02, 2015ft³	Jul. 09, 2014vessel	Jun. 27, 2014USD ($)vesselm³	Jul. 31, 2016	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)leaseagreement	Dec. 31, 2016USD ($)leaseagreement	Dec. 31, 2016USD ($)leaseagreementm³	Dec. 31, 2016USD ($)leaseagreement	Dec. 31, 2016USD ($)leaseagreementbuilding	Dec. 31, 2016USD ($)leaseagreementvessel	Dec. 31, 2016USD ($)leaseagreement	Dec. 31, 2016USD ($)leaseagreementft³	Dec. 31, 2015USD ($)lease	Dec. 31, 2014USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 22, 2014USD ($)
Long-term Purchase Commitment [Line Items]
Number of vessels | vessel												35,000
Payments made to commitments							$ 357,602	$ 357,602	$ 357,602	$ 357,602	$ 357,602	$ 357,602	$ 357,602	$ 357,602	$ 424,868
Number of capital leases | lease							2	2	2	2	2	2	2	2
Joint venture ownership percentage							100.00%	100.00%	100.00%	100.00%	100.00%	100.00%	100.00%	100.00%
Equity income								$ 62,307							$ 84,171	$ 115,478
Settled Litigation
Long-term Purchase Commitment [Line Items]
Equity income								20,300
Ras Gas Two Lng Carriers
Long-term Purchase Commitment [Line Items]
Partnership interest owned										70.00%
Ras Gas Two Lng Carriers | Foreign Tax Authority
Long-term Purchase Commitment [Line Items]
Present value of the lease rental increase claim							$ 60,000	$ 60,000	$ 60,000	$ 60,000	$ 60,000	$ 60,000	$ 60,000	$ 60,000
Corporate Joint Venture | Settled Litigation
Long-term Purchase Commitment [Line Items]
Number of capital leases | lease															1
Litigation settlement						$ 39,000
Teekay Nakilat Corporation
Long-term Purchase Commitment [Line Items]
Number of vessels | vessel												3
Number of capital leases | agreement							3	3	3	3	3	3	3	3
Term of contract							30 years
Description of capital leases, indemnification agreements							Under the terms of the leasing arrangements for the RasGas II LNG Carriers, the lessor claimed tax depreciation on the capital expenditures it incurred to acquire these vessels. As is typical in these leasing arrangements, tax and change of law risks were assumed by the lessee, in this case the Teekay Nakilat Joint Venture. Lease payments under the lease arrangements were based on certain tax and financial assumptions at the commencement of the leases and subsequently adjusted to maintain the lessor’s agreed after-tax margin.
Security deposit against future claims																			$ 6,800
Yamal LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Joint venture ownership percentage							50.00%	50.00%	50.00%	50.00%	50.00%	50.00%	50.00%	50.00%
Bahrain LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Joint venture ownership percentage							30.00%	30.00%	30.00%	30.00%	30.00%	30.00%	30.00%	30.00%
Exmar LPG Joint Venture
Long-term Purchase Commitment [Line Items]
Joint venture ownership percentage							50.00%	50.00%	50.00%	50.00%	50.00%	50.00%	50.00%	50.00%
Modified Vessel | Bahrain LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Number of floating storage units | vessel												1
DSME | Modified Vessel | Bahrain LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Operating lease arrangement period, lessor		20 years
LNG Carriers
Long-term Purchase Commitment [Line Items]
Sale leaseback amount							$ 682,800	$ 682,800	$ 682,800	$ 682,800	$ 682,800	$ 682,800	$ 682,800	$ 682,800
Number of carrier newbuildings | building											4
Number of capital leases | lease							2	2	2	2	2	2	2	2
Term of contract					10 years
Liquefied Natural Gas | DSME
Long-term Purchase Commitment [Line Items]
Number of vessels | vessel												7
Payments made to commitments							$ 316,100	$ 316,100	$ 316,100	$ 316,100	$ 316,100	$ 316,100	$ 316,100	$ 316,100
Liquefied Natural Gas | Hyundai Samho Heavy Industries Co Ltd
Long-term Purchase Commitment [Line Items]
Number of vessels | lease													2
Payments made to commitments							41,500	41,500	41,500	41,500	41,500	$ 41,500	$ 41,500	41,500
Asset under Construction
Long-term Purchase Commitment [Line Items]
Number of vessels | vessel												15,000
Asset under Construction | Forecast
Long-term Purchase Commitment [Line Items]
Contractual obligation																	$ 536,700	$ 709,700
Asset under Construction | Yamal LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Number of vessels			6									6	6
Payments made to commitments							$ 153,300	153,300	$ 153,300	$ 153,300	$ 153,300	$ 153,300	$ 153,300	$ 153,300
Volume of vessels (in cubic meter) | m³									172
Cost of construction								$ 2,100,000
Asset under Construction | BG Joint Venture | Shipbuilding supervision and crew training services
Long-term Purchase Commitment [Line Items]
Number of vessels				4								4	4
Number of capital leases | lease							4	4	4	4	4	4	4	4
Volume of vessels (in cubic meter) | m³				174
Cost of construction				$ 1,000,000
Secured financing							$ 137,100	$ 137,100	$ 137,100	$ 137,100	$ 137,100	$ 137,100	$ 137,100	$ 137,100
Amounts due				$ 20,300			$ 10,900	10,900	$ 10,900	$ 10,900	$ 10,900	$ 10,900	$ 10,900	$ 10,900	$ 16,500	$ 20,300
Asset under Construction | Exmar LPG Joint Venture | Shipbuilding supervision and crew training services
Long-term Purchase Commitment [Line Items]
Number of vessels | vessel												4
Asset under Construction | LNG Carriers
Long-term Purchase Commitment [Line Items]
Number of carrier newbuildings | building											4
LNG Receiving and Regasification Terminal | Bahrain LNG Joint Venture
Long-term Purchase Commitment [Line Items]
Cost of construction								$ 960,000
Capacity of production facility, per day (in cubic feet) | ft³														800,000,000
Operating lease arrangement period, lessor		20 years					20 years
LNG Receiving and Regasification Terminal | Bahrain LNG Joint Venture | Scenario, Plan
Long-term Purchase Commitment [Line Items]
Long term purchase commitment debt financing secured percentage										75.00%
LNG Receiving and Regasification Terminal | Bahrain LNG Joint Venture | Maximum
Long-term Purchase Commitment [Line Items]
Capacity of production facility, per day (in cubic feet) | ft³		800,000,000
Subsequent Event | LNG Carriers
Long-term Purchase Commitment [Line Items]
Sale leaseback amount	$ 174,300
Number of carrier newbuildings | building	1
Term of contract	10 years

Supplemental Cash Flow Infor107

Supplemental Cash Flow Information - Changes in Operating Assets and Liabilities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Accounts receivable	$ 5,494	$ (5,140)	$ 9,957
Prepaid expenses	745	(494)	1,781
Accounts payable	2,791	2,127	(1,098)
Accrued liabilities	(1,572)	(1,581)	(6,759)
Unearned revenue and long-term unearned revenue	(3,218)	(562)	(536)
Restricted cash	(10,808)	(2,785)	0
Advances to and from affiliates	(9,699)	(23,714)	17,953
Other operating assets and liabilities	(4,402)	(2,038)	(2,476)
Total	$ (20,669)	$ (34,187)	$ 18,822

Supplemental Cash Flow Infor108

Supplemental Cash Flow Information - Additional Information (Detail) $ in Thousands	Nov. 13, 2014USD ($)	Dec. 31, 2016USD ($)lease	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 27, 2014USD ($)	Feb. 01, 2014USD ($)
Schedule Of Supplemental Cash Flow [Line Items]
Cash interest paid on long-term debt, advances from affiliates and capital lease obligations		$ 100,900	$ 94,500	$ 128,700
Income taxes paid		4,900	7,800	2,300
Acquisition cost of vessels and associated fixed-rate contracts		$ 344,987	191,969	194,255
Number of capital leases | lease		2
Value of service obligation		$ 8,233	20,065
Teekay Tangguh Joint Venture
Schedule Of Supplemental Cash Flow [Line Items]
Advances to joint venture partner						$ 14,400
Skaugen
Schedule Of Supplemental Cash Flow [Line Items]
Acquisition cost of vessels and associated fixed-rate contracts	$ 27,000			27,000
Cash payment on acquisition				21,600
Interest-bearing loan amount				5,400
Algeciras Spirit and Huelva Spirit
Schedule Of Supplemental Cash Flow [Line Items]
Sale of vessel				56,200
Algeciras Spirit and Huelva Spirit | Capital Lease Obligations
Schedule Of Supplemental Cash Flow [Line Items]
Extinguishment of debt				56,200
Newbuildings | Shipbuilding supervision and crew training services | BG Joint Venture
Schedule Of Supplemental Cash Flow [Line Items]
Amounts due		$ 10,900	16,500	20,300	$ 20,300
Number of capital leases | lease		4
Value of service obligation		$ 22,600	$ 29,700		36,900
Newbuildings | Shipbuilding supervision and crew training services | Fair Value Asset (Liability)
Schedule Of Supplemental Cash Flow [Line Items]
Value of service obligation				$ 33,300
Newbuildings | Shipbuilding supervision and crew training services | Fair Value Asset (Liability) | BG Joint Venture
Schedule Of Supplemental Cash Flow [Line Items]
Amounts due					16,500
Value of service obligation					$ 33,300

Total Capital and Net Income109

Total Capital and Net Income Per Common Unit - Additional Information (Detail) - USD ($)	Oct. 05, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Capital Unit [Line Items]
Days after year-end where limited partner's have right to receive cash distribution		45 days
Minimum percentage of holding by unitholders to remove general partner		66.67%
Net income		$ 157,965,000	$ 217,510,000	$ 218,927,000
Common Units | Maximum
Capital Unit [Line Items]
Cash distribution per unit (USD per share)		$ 0.4625	$ 0.4625	$ 0.4625
Teekay Corporation
Capital Unit [Line Items]
General partner interest percentage		2.00%
Public
Capital Unit [Line Items]
General partner's proportionate contribution		68.30%
Limited Partners
Capital Unit [Line Items]
Distributions payable			$ 0	$ 0
Limited Partners | Common Units
Capital Unit [Line Items]
Net income		$ 134,977,000	$ 174,607,000	$ 174,251,000
Limited Partners | Preferred Units
Capital Unit [Line Items]
Net income		$ 2,719,000
Series A Preferred Stock
Capital Unit [Line Items]
Dividend rate, percentage	9.00%	9.00%

Total Capital and Net Income110

Total Capital and Net Income Per Common Unit - Incentive Distributions (Detail)	12 Months Ended
	Dec. 31, 2016$ / shares
Unitholders
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Minimum quarterly distribution of $0.4125	98.00%
Up to $0.4625	98.00%
Above $0.4625 up to $0.5375	85.00%
Above $0.5375 up to $0.6500	75.00%
$0.6500	50.00%
General Partner
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Minimum quarterly distribution of $0.4125	2.00%
Up to $0.4625	2.00%
Above $0.4625 up to $0.5375	15.00%
Above $0.5375 up to $0.6500	25.00%
$0.6500	50.00%
Minimum quarterly distribution of $0.4125 | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	$ 0.4125
Up to $0.4625 | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	0.4625
Above $0.4625 up to $0.5375 | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	0.4625
Above $0.4625 up to $0.5375 | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	0.5375
Above $0.5375 up to $0.6500 | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	0.5375
Above $0.5375 up to $0.6500 | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	0.65
Above $0.6500 | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Incentive distribution, distribution (USD per share)	$ 0.65

Total Capital and Net Income111

Total Capital and Net Income Per Common Unit - Issuances of Common Units (Detail) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Jul. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Capital Unit [Line Items]
Units Issued (shares)	3,090,000		1,173,428	1,050,463
Offering Price (USD per share)	$ 44.65
Gross Proceeds	$ 140,784		$ 36,274	$ 42,556
Net Proceeds	$ 140,484		$ 35,374	$ 41,655
Teekay Corporation's Ownership After the Offering	33.96%
Preferred Units
Capital Unit [Line Items]
Units Issued (shares)		5,000,000
Offering Price (USD per share)		$ 25
Gross Proceeds		$ 125,000
Proceeds from Issuance of Preferred Units		$ 120,707

Total Capital and Net Income112

Total Capital and Net Income Per Common Unit - Issuances of Common Units (Footnotes) (Detail) - USD ($) $ / shares in Units, $ in Thousands	Oct. 05, 2016	Jan. 31, 2015	Dec. 31, 2014	Jul. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	May 31, 2013
Capital Unit [Line Items]
Issuance of new common units, maximum aggregate amount								$ 100,000
Units Issued (shares)				3,090,000		1,173,428	1,050,463
Net Proceeds				$ 140,484		$ 35,374	$ 41,655
Continuous Offering Program 2014
Capital Unit [Line Items]
Units Issued (shares)			160,000
Net Proceeds		$ 6,800
Series A Preferred Stock
Capital Unit [Line Items]
Dividend rate, percentage	9.00%				9.00%
Redemption price (USD per share)	$ 25
Teekay Corporation
Capital Unit [Line Items]
General partner interest percentage					2.00%

Unit-Based Compensation (Detail

Unit-Based Compensation (Detail) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units granted (in shares)	132,582	32,054	31,961
Aggregate value of units issued	$ 1.5	$ 1.1	$ 1.3
Payment award description				Each restricted unit is equal in value to one of the Partnership's common units plus reinvested distributions from the grant date to the vesting date.
Restricted units, vesting period				3 years
Restricted units expense				$ 1.3	$ 1.2	$ 1
Non-management directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units granted (in shares)	32,723				10,447	9,521
Aggregate value of units issued	$ 0.4

Restructuring Charges (Detail)

Restructuring Charges (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restructuring Cost and Reserve [Line Items]
Restructuring charges	$ 0	$ 4,001,000	$ 1,989,000
Compania Espanole De Petroles
Restructuring Cost and Reserve [Line Items]
Restructuring charges	0	0	$ 2,000,000
Restructuring charge outstanding	700,000	700,000
Restructuring Related to Alexander Spirit
Restructuring Cost and Reserve [Line Items]
Restructuring charges		4,000,000
Restructuring charge outstanding	$ 0	$ 1,100,000

Write-Down and Loss on Sale 115

Write-Down and Loss on Sale of Vessels (Details) - USD ($) $ in Thousands	Nov. 30, 2016	May 17, 2016	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Proceeds from sale of vessels				$ 94,311	$ 0	$ 0
Centrofin
Property, Plant and Equipment [Line Items]
Loss on sale of vessels			$ 27,400
Proceeds from sale of vessels		$ 94,300
Asian Spirit
Property, Plant and Equipment [Line Items]
Loss on sale of vessels	$ 11,500
Proceeds from sale of vessels	$ 20,600

Subsequent Events (Detail)

Subsequent Events (Detail) $ in Thousands

Apr. 21, 2017USD ($)building

Apr. 20, 2017USD ($)

Feb. 28, 2017USD ($)

Jan. 23, 2017USD ($)

Jul. 31, 2016

Mar. 31, 2017USD ($)

Dec. 31, 2016USD ($)buildingvessel

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Jan. 23, 2017NOK

Dec. 21, 2016USD ($)

Jul. 31, 2013USD ($)

Subsequent Event [Line Items]

Ownership percentage

100.00%

Payments to acquire vessels

$ 345,790

$ 191,969

$ 188,855

Long-term debt

$ 1,791,226

$ 1,999,209

Number of vessels | vessel

35,000

Skaugen Gulf Petchem Carriers B.S.C

Subsequent Event [Line Items]

Ownership percentage

35.00%

Nogaholding

Subsequent Event [Line Items]

Ownership percentage

35.00%

Suffun Bahrain W.L.L.

Subsequent Event [Line Items]

Ownership percentage

30.00%

Norgas Sonoma | Subsequent Event

Subsequent Event [Line Items]

Partnership interest owned

100.00%

Payments to acquire vessels

$ 13,000

RasGas 3 Joint Venture

Subsequent Event [Line Items]

Ownership percentage

40.00%

Long-term debt

$ 610,000

RasGas 3 Joint Venture | Subsequent Event

Subsequent Event [Line Items]

Number of vessels

$ 100,000

Teekay LNG-Marubeni Joint Venture

Subsequent Event [Line Items]

Long-term debt

$ 396,000

$ 963,000

Teekay LNG-Marubeni Joint Venture | Subsequent Event

Subsequent Event [Line Items]

Equity method investments

$ 57,000

Long-term debt

335,000

Norwegian Bond Due October 2021 | Subsequent Event

Subsequent Event [Line Items]

Debt principal amount

$ 36,000

NOK 300,000,000

Repayment percentage

103.75%

Fixed interest rate

7.69%

7.69%

Secured Term loan Facility Maturing in 2026 | RasGas 3 Joint Venture

Subsequent Event [Line Items]

Long-term debt

$ 723,000

Teekay Lng | RasGas 3 Joint Venture | Subsequent Event

Subsequent Event [Line Items]

Number of vessels

$ 40,000

Torben Spirit | Subsequent Event

Subsequent Event [Line Items]

Operating lease arrangement period, lessor

10 months

Charter contract period

1 year

Sale leaseback amount

$ 125,000

LNG Carriers

Subsequent Event [Line Items]

Sale leaseback amount

$ 682,800

Term of contract

10 years

Number of carrier newbuildings | building

4

LNG Carriers | Subsequent Event

Subsequent Event [Line Items]

Sale leaseback amount

$ 174,300

Term of contract

10 years

Number of carrier newbuildings | building

1

Newbuildings

Subsequent Event [Line Items]

Number of vessels | vessel

15,000

Newbuildings | LNG Carriers

Subsequent Event [Line Items]

Number of carrier newbuildings | building

4

Liquefied Natural Gas | Newbuildings

Subsequent Event [Line Items]

Number of vessels | vessel

9