Golar LNG Limited (GLNG) 20-F 29 Mar 19 2018 FY Annual report (foreign) Financial data

Document and Entity Information

Document and Entity Information	12 Months Ended
	Dec. 31, 2018shares
Document and Entity Information [Abstract]
Entity Registrant Name	GOLAR LNG LTD
Entity Central Index Key	0001207179
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	101,302,404
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Document Type	20-F
Entity Emerging Growth Company	false
Entity Shell Company	false
Amendment Flag	false
Document Period End Date	Dec. 31, 2018

Consolidated Statements of Inco

Consolidated Statements of Income (Loss) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating revenues
Total operating revenues	$ 430,604	$ 143,537	$ 80,257
Operating expenses
Vessel operating expenses	96,860	55,946	53,163
Administrative expenses	51,542	38,031	37,302
Project development expenses	21,690	12,303	8,658
Depreciation and amortization	93,689	76,522	72,972
Impairment of non-current assets	0	0	1,706
Total operating expenses	369,607	244,094	221,364
Other operating income	36,722	0	0
Realized and unrealized gain on oil derivative instrument	16,767	15,100	0
Other operating gains - LNG trading	0	0	16
Operating income (loss)	114,486	(85,457)	(141,091)
Other non-operating expense
Net loss on loss of control of Golar Power	0	0	(8,483)
Other non-operating expense	0	(81)	(132)
Total other non-operating expense	0	(81)	(8,615)
Financial income (expense)
Interest income	10,133	5,890	2,969
Interest expense	(101,908)	(59,305)	(71,201)
(Losses) gains on derivative instruments	(30,541)	20,696	16,491
Other financial items, net	(1,481)	(69)	(7,800)
Net financial expense	(123,797)	(32,788)	(59,541)
Loss before equity in net (losses) earnings of affiliates, income taxes and non-controlling interests	(9,311)	(118,326)	(209,247)
Income taxes	(1,267)	(1,505)	589
Equity in net (losses) earnings of affiliates	(157,636)	(25,448)	47,878
Net loss	(168,214)	(145,279)	(160,780)
Net income attributable to non-controlling interests	(63,214)	(34,424)	(25,751)
Net loss attributable to stockholders of Golar LNG Limited	$ (231,428)	$ (179,703)	$ (186,531)
Per common share amounts:
Loss per share - basic and diluted (in dollars per share)	$ (2.30)	$ (1.79)	$ (1.99)
Cash dividends paid (in dollars per share)	$ 0.28	$ 0.2	$ 0.6
Non-collaborative Arrangement Transactions
Operating expenses
Voyage, charter-hire and commission expenses	$ 22,625	$ 22,511	$ 36,423
Collaborative Arrangement
Operating expenses
Voyage, charter-hire and commission expenses	83,201	38,781	11,140
Time and Voyage Charter | Non-collaborative Arrangement Transactions
Operating revenues
Total operating revenues	204,839	88,634	52,302
Time Charter | Collaborative Arrangement
Operating revenues
Total operating revenues	73,931	28,327	13,730
Liquefaction Services
Operating revenues
Total operating revenues	127,625	0	0
Vessel and Other Management Fees
Operating revenues
Total operating revenues	$ 24,209	$ 26,576	$ 14,225

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Loss - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
COMPREHENSIVE LOSS
Net loss	$ (168,214)	$ (145,279)	$ (160,780)
Other comprehensive income (loss):
Gain (loss) associated with pensions, net of tax	3,581	157	(556)
Share of affiliates comprehensive (loss) income	(24,324)	1,616	3,606
Other comprehensive (loss) income	(20,743)	1,773	3,050
Comprehensive loss	(188,957)	(143,506)	(157,730)
Comprehensive loss attributable to:
Stockholders of Golar LNG Limited	(252,171)	(177,930)	(183,481)
Non-controlling interests	$ (63,214)	$ (34,424)	$ (25,751)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands		Dec. 31, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents		$ 217,835	$ 214,862
Restricted cash and short-term deposits		332,033	222,265
Trade accounts receivable	[1]	64,918	14,980
Amounts due from related parties		9,425	7,898
Inventories		7,006	7,408
Other current assets		18,720	6,047
Total current assets		649,937	473,460
Non-current assets
Restricted cash		154,393	175,550
Investments in affiliates		571,782	703,225
Asset under development		20,000	1,177,489
Vessels and equipment, net		3,271,379	2,077,059
Other non-current assets		139,104	157,504
Total assets		4,806,595	4,764,287
Current liabilities
Current portion of long-term debt and short-term debt		730,257	1,384,933
Trade accounts payable	[1]	9,701	70,430
Accrued expenses	[1]	133,234	105,895
Amounts due to related parties		5,417	8,734
Other current liabilities		121,529	62,282
Total current liabilities		1,000,138	1,632,274
Non-current liabilities
Long-term debt		1,835,102	1,025,914
Amounts due to related parties		0	177,247
Other non-current liabilities		145,564	132,548
Total liabilities		2,980,804	2,967,983
Commitments and Contingencies
EQUITY
Share capital 101,302,404 common shares of $1.00 each issued and outstanding (2017: 101,118,289)		101,303	101,119
Treasury shares		(20,483)	(20,483)
Additional paid-in capital		1,857,196	1,538,191
Contributed surplus		200,000	200,000
Accumulated other comprehensive loss		(28,512)	(7,769)
Retained losses		(364,379)	(95,742)
Total stockholders' equity		1,745,125	1,715,316
Non-controlling interests		80,666	80,988
Total equity		1,825,791	1,796,304
Total liabilities and equity		$ 4,806,595	$ 4,764,287
[1]	This includes amounts arising from transactions with related parties (see note 28).

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2018	Dec. 31, 2017
EQUITY
Common shares, shares issued (in shares)	101,302,404	101,118,289
Common shares, shares outstanding (in shares)	101,302,404	101,118,289
Common shares, par value (in dollars per share)	$ 1	$ 1

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating activities
Net loss		$ (168,214)	$ (145,279)	$ (160,780)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization		93,689	76,522	72,972
Amortization of deferred charges and debt guarantees		7,734	(900)	13,732
Equity in net losses (earnings) of affiliates		157,636	25,448	(47,878)
Net loss on loss of control of Golar Power		0	0	8,483
Dividends received		15,837	27,553	26,515
Compensation cost related to stock options		11,481	8,991	5,816
Net foreign exchange losses		1,997	1,620	1,429
Change in fair value of derivative instruments		38,610	(24,498)	(26,644)
Amortization of deferred tax benefits on intra-group transfers		0	0	(1,715)
Impairment of non-current assets		0	0	1,706
Impairment of loan receivable		0	0	7,627
Change in assets and liabilities:
Trade accounts receivable		(49,938)	(11,413)	(567)
Inventories		402	(151)	987
Other current and non-current assets		(13,532)	(80,897)	14,615
Amounts due to related companies		(16,540)	(27,130)	(9,444)
Trade accounts payable		(24,813)	1,593	(28,511)
Accrued expenses		12,191	28,666	(3,410)
Other current and non-current liabilities	[1]	40,164	99,886	9,680
Net cash provided by (used in) operating activities		116,674	(35,089)	(115,387)
Investing activities
Additions to vessels and equipment		(33,111)	(1,349)	(14,477)
Additions to newbuildings		0	0	(19,220)
Additions to asset under development		(116,715)	(390,552)	(200,821)
Additions to investments in affiliates		(95,503)	(123,107)	(10,200)
Dividends received		33,185	25,113	29,002
Short-term loan granted		0	0	(1,000)
Proceeds from disposals to Golar Partners, net of cash disposed		9,652	70,000	107,247
Proceeds from loss of control of Golar Power, net of cash disposed		0	0	113,321
Net cash (used in) provided by investing activities		(202,492)	(419,895)	3,852
Financing activities
Proceeds from short-term and long-term debt (including related parties)		1,177,748	928,432	405,817
Payment for capped call in connection with bond issuance		0	(31,194)	0
Repayments of short-term and long-term debt (including related parties)		(994,874)	(446,626)	(271,858)
Financing costs paid		(1,817)	(1,564)	(8,372)
Cash dividends paid		(42,873)	(20,438)	(54,348)
Proceeds from exercise of share options		2,686	(1,167)	1,435
Purchase of treasury shares		0	0	(8,214)
Proceeds from issuance of equity		0	0	169,876
Acquisition of non-controlling interests		36,532	0	0
Net cash provided by financing activities		177,402	427,443	234,336
Net increase (decrease) in cash, cash equivalents and restricted cash		91,584	(27,541)	122,801
Cash, cash equivalents and restricted cash at beginning of period		612,677	640,218	517,417
Cash, cash equivalents and restricted cash at end of period		704,261	612,677	640,218
Supplemental disclosure of cash flow information:
Interest paid, net of capitalized interest		29,832	34,479	24,828
Income taxes paid		1,469	1,240	555
Energy Related Derivative
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Change in fair value of derivative instruments		$ 9,970	$ (15,100)	$ 0
[1]	Includes accretion of discount on convertible bonds of $13.5 million, $11.8 million and $5.7 million for the years ended December 31, 2018, 2017 and 2016, respectively.

Consolidated Statements of Ca_2

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Statement of Cash Flows [Abstract]
Accretion of interest on bond	$ 13,500	$ 11,800	$ 5,700
Cash and cash equivalents	217,835	214,862	224,190
Restricted cash and short-term deposits (current portion)	332,033	222,265	183,693
Restricted cash (non-current portion)	154,393	175,550	232,335
Cash, cash equivalents, restricted cash and restricted cash equivalents	$ 704,261	$ 612,677	$ 640,218

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Thousands	Total	Share Capital	Treasury Shares	Additional Paid-in Capital	Contributed Surplus	Accumulated Other Comprehensive Loss	Retained Earnings (Losses)	Non-controlling Interests
Balance at beginning of the period at Dec. 31, 2015	$ 1,916,179	$ 93,547	$ (12,269)	$ 1,317,806	$ 200,000	$ (12,592)	$ 308,874	$ 20,813
Increase (Decrease) in Stockholders' Equity
Net loss	(160,780)						(186,531)	25,751
Dividends	(18,693)						(18,693)
Exercise of share options	1,435	59		1,376
Employee stock compensation	7,865			7,865
Forfeiture of share options	(892)			(892)
Net proceeds from issuance of shares	169,876	7,475		162,401
Other comprehensive income	3,050					3,050
Treasury shares	(8,214)		(8,214)
Balance at end of the period at Dec. 31, 2016	1,909,826	101,081	(20,483)	1,488,556	200,000	(9,542)	103,650	46,564
Increase (Decrease) in Stockholders' Equity
Net loss	(145,279)						(179,703)	34,424
Dividends	(19,689)						(19,689)
Exercise of share options	(1,166)	38		(1,204)
Employee stock compensation	11,098			11,098
Forfeiture of share options	(120)			(120)
Other comprehensive income	1,773					1,773
Issuance of convertible bonds	39,861			39,861
Balance at end of the period at Dec. 31, 2017	1,796,304	101,119	(20,483)	1,538,191	200,000	(7,769)	(95,742)	80,988
Increase (Decrease) in Stockholders' Equity
Net loss	(168,214)						(231,428)	63,214
Dividends	(57,958)						(37,076)	(20,882)
Exercise of share options	2,686	184		2,502
Employee stock compensation	13,992			14,125			(133)
Forfeiture of share options	(2,090)			(2,090)
Effect of consolidating Hilli Lessor VIE	28,703							28,703
Conversion of debt to equity (see note 20)	55,134							55,134
Other comprehensive income	(20,743)					(20,743)
Issuance of convertible bonds	177,977			304,468				(126,491)
Balance at end of the period at Dec. 31, 2018	$ 1,825,791	$ 101,303	$ (20,483)	$ 1,857,196	$ 200,000	$ (28,512)	$ (364,379)	$ 80,666

GENERAL

GENERAL	12 Months Ended
	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GENERAL	1. GENERAL Golar LNG Limited (the "Company" or "Golar") was incorporated in Hamilton, Bermuda on May 10, 2001 for the purpose of acquiring the liquefied natural gas ("LNG") shipping interests of Osprey Maritime Limited, which was owned by World Shipholding Limited. As of December 31, 2018 , our fleet comprises of 12 LNG carriers, one Floating Storage Regasification Unit ("FSRU") and one Floating Liquefaction Natural Gas vessel ("FLNG"). We also operate, under management agreements, Golar LNG Partners LP's ("Golar Partners" or the "Partnership") fleet of 10 vessels and Golar Power Limited's ("Golar Power") fleet of three vessels. Collectively with Golar Partners and Golar Power, our combined fleet is comprised of 18 LNG carriers, eight FSRUs and one FLNG. We are listed on the Nasdaq under the symbol: GLNG. As used herein and unless otherwise required by the context, the terms "Golar", the "Company", "we", "our" and words of similar import refer to Golar or anyone or more of its consolidated subsidiaries, or to all such entities. Going Concern The financial statements have been prepared on a going concern basis. A pre-condition of the Golar Tundra lease financing with CMBL (refer to note 5 "Variable Interest Entities" of our consolidated financial statements included herein) is for the FSRU to be employed under an effective charter. Under the terms of our sale and lease back facility for the Golar Tundra , by virtue of our prior termination of the WAGL charter, we are required to find a replacement charter by June 30, 2019 or we could be required to refinance the FSRU. Accordingly, to address our anticipated working capital requirements over the next 12 months, in the event we are unable to secure a charter for the Golar Tundra , we are currently exploring our refinancing options, including extension of the lenders’ deadlines for satisfaction of such. While we believe we will be able to obtain the necessary funds from these refinancings, we cannot be certain that the proposed new credit facilities will be executed in time or at all. However, we have a track record of successfully financing and refinancing our vessels, even in the absence of term charter coverage. In addition to vessel refinancings, if market and economic conditions are favorable, we may also consider further issuances of corporate debt or equity to increase liquidity. To address our anticipated working capital requirements over the next 12 months, we remain in ongoing negotiations with financial institutions for funding the investments for our conversion projects including potential investments into our joint venture, and repayment of long-term debt balances. Sources of funding for our medium and long-term liquidity requirements include new loans, refinancing of existing financing arrangements, public and private debt or equity offerings, and potential sales of our interests in our vessel owning subsidiaries operating under long-term charters. In February 2019, Golar entered into an agreement with BP for the charter of a FLNG unit, Gimi , for a 20 -year period expected to commence in the second half of 2022. LNG carrier Gimi has been relocated from layup to Keppel Shipyard where a site team has been assembled. Golar also entered into a Shareholders Agreement with Keppel Capital in respect of their participation in a 30% share of the project. Total conversion works, which incorporate lessons learned from FLNG Hilli Episeyo including some improvements and modifications, are expected to cost approximately $1.3 billion . We anticipate annual contracted revenues less forecasted operating costs of approximately $215 million per year. Golar is in the final stages of receiving an underwritten credit commitment for a $700 million long-term financing facility with a syndicate of international banks that will also be available during construction. Accordingly, we believe that, based on our plans as outlined above, we will have sufficient facilities to meet our anticipated liquidity requirements for our business for at least the next 12 months as of March 29, 2019 and that our working capital is sufficient for our present requirements. While we cannot be certain of execution or timing of all or any of the above financings, we are confident of our ability to do so.We have performed stress testing of our forecast cash reserves under various theoretical scenarios, which include assumptions such as extremely prudent revenue contributions from our fleet, full operating costs and maintaining our dividend payments based on our most recent pay out, and accordingly are confident of our ability to manage through the near term cash requirements.

BASIS OF PREPARATION AND SIGNIF

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	2. BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES Basis of preparation These consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP"). The accounting policies set out below have been applied consistently to all periods in these consolidated financial statements, unless otherwise noted. Principles of consolidation A variable interest entity ("VIE") is defined by the accounting standard as a legal entity where either (a) equity interest holders as a group lack the characteristics of a controlling financial interest, including decision making ability and an interest in the entity's residual risks and rewards, or (b) the equity holders have not provided sufficient equity investment to permit the entity to finance its activities without additional subordinated financial support, or (c) the voting rights of some investors are not proportional to their obligations to absorb the expected losses of the entity, their rights to receive the expected residual returns of the entity, or both and substantially all of the entity's activities either involve or are conducted on behalf of an investor that has disproportionately few voting rights. A party that is a variable interest holder is required to consolidate a VIE if the holder has both (a) the power to direct the activities that most significantly impact the entity's economic performance and (b) the obligation to absorb losses that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The accompanying consolidated financial statements include the financial statements of the entities listed in notes 4 and 5. Investments in entities in which we directly or indirectly hold more than 50% of the voting control are consolidated in the financial statements, as well as certain variable interest entities in which the Company is deemed to be subject to a majority of the risk of loss from the VIE's activities or entitled to receive a majority of the entity's residual returns, or both. All inter-company balances and transactions are eliminated. The non-controlling interests of the above-mentioned subsidiaries were included in the consolidated balance sheets and statements of income as "Non-controlling interests". Changes in our ownership interest while we retain a controlling financial interest in a subsidiary are accounted for as equity transactions. The carrying amount of the non-controlling interest is adjusted to reflect our changed ownership interest, with any difference between the fair value of consideration and the amount of the adjusted non-controlling interest being recognized in equity. We recognize a gain or loss when a subsidiary issues its stock to third parties at a price per share in excess or below its carrying value resulting in a reduction in our ownership interest in the subsidiary. The gain or loss is recorded in the line "Additional paid-in capital". When a consolidated subsidiary issues preferred stock, they are classified as equity. Preferred stock issued by a consolidated subsidiary to non-controlling interests are recorded as non-controlling interests for the amount of the proceeds received upon issuance. Foreign currencies Our functional currency is the U.S. dollar as the majority of the revenues are received in U.S. dollars and a majority of our expenditures are incurred in U.S. dollars. Our reporting currency is U.S. dollars. Transactions in foreign currencies during the year are translated into U.S. dollars at the exchange rates in effect at the date of the transaction. Monetary assets and liabilities are translated using exchange rates at the balance sheet date. Non-monetary assets and liabilities are translated using historical exchange rates. Foreign currency transaction and translation gains or losses are included in the consolidated balance sheets and consolidated statements of income. Use of estimates The preparation of financial statements in accordance with US GAAP requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. As of December 31, 2018 , we leased eight vessels from wholly-owned special purpose vehicles ("Lessor SPVs") of financial institutions in connection with our sale and leaseback transactions. While we do not hold any equity investments in these Lessor SPVs, we have determined that we are the primary beneficiary of these entities and, accordingly, we are required to consolidate these VIEs into our financial results. The key line items impacted by our consolidation of these VIEs are short-term and long-term debt, restricted cash and short-term deposits, non-controlling interests, interest income and interest expense. In consolidating these lessor VIEs, on a quarterly basis, we must make assumptions regarding (i) the debt amortization profile; (ii) the interest rate to be applied against the VIEs’ debt principal; and (iii) the VIE's application of cash receipts. Our estimates are therefore dependent upon the timeliness of receipt and accuracy of financial information provided by these lessor VIE entities. Upon receipt of the audited annual financial statements of the lessor VIEs, we will make a true-up adjustment for any material differences. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual or scrap value, charter rates, ship operating expenses, utilization and drydocking requirements. In relation to the oil derivative instrument (see note 27), the fair value was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the liquefaction tolling agreement ("LTA"). Significant inputs used in the valuation of the oil derivative instrument include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our oil derivative instrument is recognized in each period in current earnings in "Realized and unrealized gain on oil derivative instrument". The realized and unrealized gain on oil derivative instrument is as follows: (in thousands of $) Year Ended 2018 2017 Realized gain on oil derivative instrument 26,737 — Unrealized (loss) gain on oil derivative instrument (9,970 ) 15,100 16,767 15,100 The unrealized gain results from movement in oil prices above a contractual floor price over term of the LTA; the realized gain results from monthly billings above the base tolling fee under the LTA. Fair value measurements We account for fair value measurement in accordance with the accounting standards guidance using fair value to measure assets and liabilities. The guidance provides a single definition of fair value, together with a framework for measuring it, and requires additional disclosure about the use of fair value to measure assets and liabilities. Revenue and related expense recognition Time charter agreements Revenues include minimum lease payments under time charters, fees for positioning and repositioning vessels, and gross pool revenues. Revenues generated from time charters, which we generally classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Initial direct costs (those directly related to the negotiation and consummation of the lease) are deferred and allocated to earnings over the lease term. Rental income and expense are amortized over the lease term on a straight-line basis. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is offhire, for example when the vessel is undergoing repairs. These expenses are recognized as incurred. Vessel operating expenses, which are recognized when incurred, include crewing, repairs and maintenance, insurance, stores, lube oils, communication expenses and third party management fees. Bunkers consumption represents mainly bunkers consumed during unemployment and off-hire. Liquefaction services revenue Liquefaction services revenue is generated from a LTA entered into with our customer. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. The liquefaction services capacity provided to our customer is considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. Contractual payment terms for liquefaction services is monthly in arrears, after services have been provided, generally resulting in the recognition of contract assets. Contract assets are regularly assessed for impairment. Contract liabilities arise when the customer makes payments in advance of receiving services. The term between when invoicing and when payment is due is not significant. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Management fees Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. Commercial and technical vessel-related services include vessel maintenance, providing vessel crew, making arrangements for vessel insurance, bunkering, provisions and stores, invoicing and collecting vessel hire. Corporate and administrative services include corporate services, group accounting, treasury, legal, tax, consultancy and other administrative services. These services are provided to our customers Golar Partners and Golar Power. Our contracts generally have an initial contract term of one year or less, after which the arrangement continues with a short notice period to end the contract, ranging from 30 days to 180 days. Our management services provided are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. Contractual payment terms for management fees generally allow for billing and payment in advance of services being provided. However, contract liabilities did not arise because there was no billing in recognition for services rendered in future periods at the reporting date. Contract assets arise when we render management services in advance of receiving payment from our customers. Contract assets are regularly assessed for impairment. The transaction price is generally considered variable consideration given the key driver of consideration is actual costs incurred in a given period, which varies each period according to activity levels. The entire amount of the transaction price is allocated to the single performance obligation identified. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount we have the right to invoice. Cool Pool Pool revenues and expenses under the Cool Pool arrangement have been accounted for in accordance with the guidance for collaborative arrangements. In relation to our vessels participating within the pool, voyage expenses and commissions from collaborative arrangements include an allocation of our net results from the pool to the other participants. Each participants' share of the net pool revenues is based on the number of pool points attributable to its vessels and the number of days such vessels participated in the pool. We have presented our share of the net income earned under the Cool Pool arrangement across a number of line items in the income statement. For net revenues and expenses incurred relating specifically to Golar’s vessels, and for which we are deemed the principal, these will be presented gross on the face of the income statement in the line items "Time and voyage charter revenues" and "Voyage, charterhire and commission expenses". For pool net revenues generated by the other participants in the pooling arrangement, these will be presented separately in revenue and expenses from collaborative arrangements. Refer to note 28 for an analysis of the income statement effect for the pooling arrangement. Project development expenses With effect from the year ended December 31, 2018, we presented a new line item in operating expenses on the face of the statements of income. The new line item, "Project development expenses", includes the costs associated with pursuing future contracts and developing our pipeline of activities that have not met our internal threshold for capitalization. Previously, these costs were presented within "Administrative expenses" along with our general overhead costs. We believe that the introduction of this new line item in the statements of income provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods. The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted December 31, 2016 Administrative expenses 45,960 (8,658 ) 37,302 Project development expenses — 8,658 8,658 December 31, 2017 Administrative expenses 50,334 (12,303 ) 38,031 Project development expenses — 12,303 12,303 Cash and cash equivalents We consider all demand and time deposits and highly liquid investments with original maturities of three months or less to be equivalent to cash. Restricted cash and short-term deposits Restricted cash consists of bank deposits which may only be used to settle certain pre-arranged loans, bid bonds in respect of tenders for projects we have entered into, cash collateral required for certain swaps, and other claims which require us to restrict cash. Short-term deposits represent highly liquid deposits placed with financial institutions, primarily from our consolidated VIEs, which are readily convertible into known amounts of cash with original maturities of less than 12 months. Trade accounts receivables Trade receivables are presented net of allowances for doubtful balances. At each balance sheet date, all potentially uncollectible accounts are assessed individually for purposes of determining the appropriate provision for doubtful accounts. Inventories Inventories, which are comprised principally of fuel, lubricating oils and vessel spares, are stated at the lower of cost and net realizable value. Cost is determined on a first-in, first-out basis. Investments in affiliates Affiliates are entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but over which we do not exercise control or have the power to control the financial and operational policies. Investments in these entities are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the participating rights of non-controlling interests. Under this method, we record our investment in the affiliate at cost (or fair value if a consequence of deconsolidation), and adjust the carrying amount for our share of the earnings or losses of the affiliate subsequent to the date of the investment and report the recognized earnings or losses in income. Dividends received from an affiliate reduce the carrying amount of the investment. The excess, if any, of the purchase price over book value of our investments in equity method affiliates, or basis difference, is included in the consolidated balance sheets as "Investments in affiliates". We allocate the basis difference across the assets and liabilities of the affiliate, with the residual assigned to goodwill. Any negative goodwill is recognized immediately in the income statement as a gain on bargain purchase. The basis difference will then be amortized through the consolidated statements of income as part of the equity method of accounting. When our share of losses in an affiliate equals or exceeds its interest, we do not recognize further losses, unless we have incurred obligations or made payments on behalf of the affiliate. We recognize gains and losses in earnings for the issuance of shares by our affiliates, provided that the issuance of such shares qualifies as a sale of such shares. Cost method investments Cost method investments are initially recorded at cost and reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Dividends received from cost method investments are recorded in the consolidated statements of income in the line item "Dividend income". Vessels and equipment Vessels and equipment are stated at cost less accumulated depreciation. The cost of vessels and equipment, less the estimated residual value, is depreciated on a straight-line basis over the assets' remaining useful economic lives. Management estimates the residual values of our vessels based on a scrap value cost of steel and aluminum times the weight of the ship noted in lightweight ton. Residual values are periodically reviewed and revised to recognize changes in conditions, new regulations or other reasons. The cost of building mooring equipment is capitalized and depreciated over the initial lease term of the related agreement. Refurbishment costs incurred during the period are capitalized as part of vessels and equipment and depreciated over the vessels' remaining useful economic lives. Refurbishment costs are costs that appreciably increase the capacity, or improve the efficiency or safety of vessels and equipment. Drydocking expenditures are capitalized when incurred and amortized over the period until the next anticipated drydocking, which is generally five years. For vessels that are newly built or acquired, we have adopted the "built-in overhaul" method of accounting. The built-in overhaul method is based on the segregation of vessel costs into those that should be depreciated over the useful life of the vessel and those that require drydocking at periodic intervals to reflect the different useful lives of the components of the assets. The estimated cost of the drydocking component is amortized until the date of the first drydocking following acquisition, upon which the cost is capitalized and the process is repeated. When a vessel is disposed, any unamortized drydocking expenditure is charged against income in the period of disposal. Vessel reactivation costs incurred on vessels leaving lay-up include both costs of a capital and expense nature. The capital costs include the addition of new equipment or modifications to the vessel which enhance or increase the operational efficiency and functionality of the vessel. These expenditures are capitalized and depreciated over the remaining useful life of the vessel. Expenditures of a routine repairs and maintenance nature that do not improve the operating efficiency or extend the useful lives of the vessels are expensed as incurred as mobilization costs. Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRUs and FLNG) 40 years Vessels - converted FSRUs 20 years from conversion date Vessels - FLNG 30 years from conversion date Drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years Asset under development An asset is classified as asset under development when there is a firm commitment from us to proceed with the construction of the asset and the likelihood of conversion is virtually certain to occur. An asset under development is classified as non-current and is stated at cost. All costs incurred during the construction of the asset, including conversion installment payments, interest, supervision and technical costs are capitalized. Interest costs directly attributable to construction of the asset is added to the cost of the asset. Capitalization ceases, and depreciation commences, once the asset is completed and available for its intended use. Interest costs capitalized Interest is capitalized on all qualifying assets that require a period of time to get them ready for their intended use. Qualifying assets consist of vessels under construction, assets under development and vessels undergoing conversion into FSRUs or FLNGs for our own use. In addition, certain equity method investments may be considered qualifying assets prior to commencement of their planned principal operation. The interest capitalized is calculated using the rate of interest on the loan to fund the expenditure or our weighted average cost of borrowings, where appropriate, from commencement of the asset development until substantially all the activities necessary to prepare the assets for its intended use are complete. If our financing plans associate a specific borrowing with a qualifying asset, we use the rate on that borrowing as the capitali z ation rate to be applied to that portion of the average accumulated expenditures for the asset provided that does not exceed the amount of that borrowing. We do not capitali z e amounts beyond the actual interest expense incurred in the period. Asset retirement obligation An asset retirement obligation, or ARO, is a liability associated with the eventual retirement of a fixed asset. The fair value of an ARO is recorded as a liability in the period when the obligation arises. The fair value of the ARO is measured using expected future discounted cash outflows. When the liability is recognized, we also capitalize the related ARO cost by adding it to the carrying amount of the related fixed asset. Each period, the liability is increased for the change in its present value. Changes in the amount or timing of the estimated ARO are recorded as an adjustment to the related liability and asset. Held-for-sale assets and disposal group Individual assets or subsidiaries to be disposed of, by sale or otherwise in a single transaction, are classified as held-for-sale if all of the following criteria are met at the period end: • Management, having the authority to approve the action, commits to a plan to sell the assets or subsidiaries; • The asset or subsidiaries are available for immediate sale in its present condition subject only to terms that are usual and customary for such sales; • An active program to locate a buyer and other actions required to complete the plan to sell have been initiated; • The sale is probable; and • The transfer is expected to qualify for recognition as a completed sale, within one year. The term probable refers to a future sale that is likely to occur, the asset or subsidiaries (disposal group) is being actively marketed for sale at a price that is reasonable in relation to its current fair value and actions required to complete the plan indicate that it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn. A disposal group is classified as discontinued operations if the following criteria are met: (1) a component of an entity or group of components that has been disposed of by sale, disposed of other than by sale or is classified as held-for-sale that represents a strategic shift that has or will have a major effect on our financial results or (2) an acquired business or non-profit activity (the entity to be sold) that is classified as held-for-sale on the date of the acquisition. Assets or subsidiaries held-for-sale are carried at the lower of their carrying amount and fair value less costs to sell. Interest and other expenses attributable to the liabilities of a disposal group classified as held-for-sale shall continue to be accrued. On classification as held-for-sale, the assets are no longer depreciated. If, at any time, the criteria for held-for-sale is no longer met, then the asset or disposal group will be reclassified to held and used. The asset or disposal group will be valued at the lower of the carrying amount before the asset or disposal group was classified as held-for-sale (as adjusted for any subsequent depreciation and amortization), and its fair value. Any adjustment to the value is shown in consolidated statements of income for the period in which the criterion for held-for-sale was not met. Impairment of long-lived assets We continually monitor events and changes in circumstances that could indicate carrying amounts of long-lived assets may not be recoverable. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows and estimates in respect of residual or scrap value. When such events or changes in circumstances are present, we assess the recoverability of long-lived assets by determining whether the carrying value of such assets will be recovered through undiscounted expected future cash flows. If the total of the future cash flows is less than the carrying amount of those assets, we recognize an impairment loss based on the excess of the carrying amount over the lower of the fair market value of the assets, less cost to sell, and the net present value ("NPV") of estimated future undiscounted cash flows from the employment of the asset ("value-in-use"). Other-than-temporary impairment of investments Where there are indicators that fair value is below carrying value of our investments, we will evaluate these for other-than-temporary impairment. Consideration will be given to (1) the length of time and the extent to which fair value is below carrying value, (2) the financial condition and near-term prospects of the investee, and (3) our intent and ability to hold the investment until any anticipated recovery. Where determined to be other-than-temporary impairment, we will recognize an impairment loss in the period in the line item "Equity in net (losses) earnings of affiliates" the consolidated statements of income. Deferred charges Costs associated with long-term financing, including debt arrangement fees, are deferred and amortized over the term of the relevant loan under the effective interest method. Amortization of debt issuance costs is included in interest expense. These costs are presented as a deduction from the corresponding liability, consistent with debt discounts. Derivatives We use derivatives to reduce market risks associated with our operations. We use interest rate swaps for the management of interest rate risk exposure. The interest rate swaps effectively convert a portion of our debt from a floating to a fixed rate over the life of the transactions without an exchange of underlying principal. We seek to reduce our exposure to fluctuations in foreign exchange rates through the use of foreign currency forward contracts. From time to time, we enter into equity swaps. Under these facilities, we swap with our counterparty (usually a major bank) the risk of fluctuations in our share price and the benefit of any dividends, for a fixed payment of LIBOR plus margin. The counterparty may acquire shares in the Company to hedge its own position. All derivative instruments are initially recorded at fair value as either assets or liabilities in the accompanying consolidated balance sheets and subsequently remeasured to fair value, regardless of the purpose or intent for holding the derivative. Where the fair value of a derivative instrument is a net liability, the derivative instrument is classified in "Other current liabilities" and "Other non-current liabilities", as appropriate, in the consolidated balance sheets. Where the fair value of a derivative instrument is a net asset, the derivative instrument is classified in "Other current assets" and "Other non-current assets", as appropriate, in the consolidated balance sheets. The changes in fair value of derivative financial instruments (excluding the oil derivative instrument) are recognized each period in current earnings in "(Losses) gains on derivative instruments" in the consolidated statements of income. We do not apply hedge accounting. The fair value of the oil derivative instrument was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA. Significant inputs used in the valuation of the oil derivative instrument include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our oil derivative instrument is recognized in each period in current earnings in "Realized and unrealized gain on oil derivative instrument". Cash flows from economic hedges are classified in the same category as the items subject to the economic hedging relationship. Changes in presentation of fair value of derivative instruments and oil derivative instrument With effect from the year ended December 31, 2018, we presented two new line items in operating activities on the face of the statements of cashflows. Given the significance of the oil derivative instrument in current year, we believe that the introduction of this new line item in the statements of cashflows provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods. The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted December 31, 2016 Change in fair value of derivative instruments — (26,644 ) (26,644 ) Change in assets and liabilities: Other current and non-current assets 14,924 (309 ) 14,615 Other current and non-current liabilities (17,273 ) 26,953 9,680 December 31, 2017 Change in fair value of derivative instruments — (24,498 ) (24,498 ) Change in assets and liabilities: Other current and non-current assets (102,453 ) 21,556 (80,897 ) Change in fair value of oil derivative instrument — (15,100 ) (15,100 ) Other current and non-current liabilities 81,844 18,042 99,886 (Losses) gains on derivative instruments With effect from the year ended December 31, 2018, we presented a new line item under financial income (expense) on the face of the statements of income. The new line item, "(Losses) gains on derivative instruments", includes the movement of our derivative instruments. Previously, these items were presented within "Other financial items, net" along with our general finance costs. We believe that the introduction of this new line item in the statements of income provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods. The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments decrease As adjusted December 31, 2016 Gains (losses) on derivative instruments — 16,491 16,491 Other financial items, net 8,691

RECENTLY ISSUED ACCOUNTING STAN

RECENTLY ISSUED ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2018
Accounting Changes and Error Corrections [Abstract]
RECENTLY ISSUED ACCOUNTING STANDARDS (Restated)	3. RECENTLY ISSUED ACCOUNTING STANDARDS Adoption of new accounting standards In May 2014, the Financial Accounting Standards Board (the “FASB”) issued ASC 606 and subsequent amendments (Topic 606). The standard provides a single, comprehensive revenue recognition model and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We adopted this guidance on January 1, 2018, under a modified retrospective approach - see note 8 for further details. The adoption of this guidance impacts presentation and disclosure of our management fee revenue only, there is no impact to recognition or measurement. In January 2016, the FASB issued ASU 2016-01 Financial Instruments-Overall (Subtopic 825-10) : Recognition and Measurement of Financial Assets and Financial Liabilities , which made targeted improvements to the recognition, measurement, presentation and disclosure of financial instruments. We adopted the amendments to this ASU on January 1, 2018 under a modified retrospective approach except for equity securities without a determinable fair value, for which a prospective approach is prescribed. The adoption of this ASU did not have a material impact on the consolidated financial statements. In August 2016, the FASB issued ASU 2016-15 Statement of Cash Flows (Topic 230) : Classification of Certain Cash Receipts and Cash Payments , which provides guidance on the disclosure and classification of certain items within the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows. Following the adoption of the amendments to ASC 230, we have made an accounting policy election to classify distributions received from equity method investees using the "cumulative earnings approach" and, as a result, certain of the dividends received have been retrospectively reclassified, where required, as cash inflows from investing activities. We reclassified $25.1 million and 29.0 million for the years ended December 31, 2017 and 2016, respectively. In November 2016, the FASB issued ASU 2016-18 Statement of Cash Flows (Topic 230): Restricted Cash , which requires that restricted cash be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts presented on the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows and related disclosures. The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the twelve months ended December 31, 2017 and 2016: (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted December 31, 2016 OPERATING ACTIVITIES Restricted cash and short-term deposits 47,834 (47,834 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 22,928 (22,928 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (74,608 ) 74,608 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash 118,955 3,846 122,801 Cash, cash equivalents and restricted cash at beginning of period 105,235 412,182 517,417 Cash, cash equivalents and restricted cash at end of period 224,190 416,028 640,218 December 31, 2017 OPERATING ACTIVITIES Restricted cash and short-term deposits 57,110 (57,110 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 11,239 (11,239 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (50,136 ) 50,136 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash (9,328 ) (18,213 ) (27,541 ) Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 214,862 397,815 612,677 In January 2017, the FASB issued ASU 2017-01 Business Combinations (Topic 805): Clarifying the Definition of a Business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. We adopted this ASU prospectively from January 1, 2018. As a result, this increases the likelihood that future vessel dropdowns may be considered the sale of an asset rather than a business. However, this will be dependent upon the facts and circumstances of each prospective transaction. There was no material impact on the adoption of this ASU on our consolidated financial statements and related disclosures. In February 2017, the FASB issued ASU 2017-05 Other Income - Gains and Losses from the Derecognition of Non-Financial Assets . This ASU clarifies the scope of guidance applicable to sales of non-financial assets and also provides guidance on partial sales of such assets. We adopted this ASU prospectively from January 1, 2018. We expect any gain or loss on sale from future dropdowns, accounted for as a disposal, will be recognized in full on the disposal date, however this will be dependent on the facts and circumstances of each prospective transaction. There was no material impact to our consolidated financial statements and related disclosures on adoption of this standard. Accounting pronouncements that have been issued but not adopted In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) and subsequent amendments. Topic 842 modifies the definition of a lease, requires periodic reassessment of the lease term and requires new disclosures. Lessors are required to classify leases as sales-type, direct financ i ng or operating, with classification affecting the pattern of income recognition and provides guidance for sale and leaseback transactions. Topic 842 requires a lessee to recognize leases on its balance sheet by recording a lease liability (representing the obligation to make future lease payments) and a right of use asset (representing the right to use the asset for the lease term). Leases for lessees will be classified as either financing or operating with classification affecting the pattern of expense recognition in the income statement. Topic 842 will become effective for us on January 1, 2019. We have applied the modified retrospective transition approach. We will elect all available practical expedients which among other things allow us to carry forward prior conclusions relating to lease identification, classification and lease term. Our election of the practical expedient providing transition relief will result in our prior periods not being restated and will continue to be represented in accordance with Topic 840. Our minimum commitments relating to our existing operating leases are outlined in note 13 to the consolidated financial statements. The most significant impact of Topic 842 relates to our accounting for our office leases which will be recorded as assets and liabilities on our Balance Sheet from adoption. We do not believe that Topic 842 will have a notable impact on our liquidity and our debt covenant compliance under our current arrangements. For contracts where we are the lessor, the practical expedients we have elected results in no change to our Balance Sheet on adoption. Our legacy leases will continue to be classified in accordance with Topic 840, while modifications and subsequent accounting will follow the accounting under Topic 842. Leases entered into on or after January 1, 2019 will be assessed under the requirements of Topic 842. New lessor presentation and disclosure requirements are introduced and will be applied to our new and existing lease agreements in our subsequent reporting. In June 2016, the FASB issued ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and subsequent amendment ASU 2018-19 Codification Improvements to Topic 326 ‘‘Financial Instruments-Credit Losses” , which requires recognition and measurement of expected credit losses for financial assets and off balance sheet credit exposures. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics covering primarily minor corrections, clarifications and codification improvements. We are evaluating the impact of these amendments on our consolidated financial statements and related disclosures, which is not expected to have material impact on our consolidated financial statements. In August 2018, the FASB issued ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement . These amendments change the disclosures for fair value measurements - removing or modifying certain existing disclosure requirements, and adding new disclosure requirements. The guidance is effective for us commencing January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In August 2018, the FASB issued ASU 2018-14 Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans . These amendments change the disclosures for defined benefit plans - removing or clarifying certain existing disclosure requirements, and adding new disclosure requirements. The guidance is effective on a retrospective basis for us on January 1, 2021 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In August 2018, the FASB issued ASU 2018-15 Intangibles-Goodwill and Other- Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract . These amendments change the definition of a hosting arrangement and requires the capitalization of certain implementation costs. The guidance is effective on either a retrospective or prospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In October 2018, the FASB issued ASU 2018-17 Consolidation (Topic 810) - Targeted Improvements to Related Party Guidance for Variable Interest Entities . This amendment clarifies guidance for considering whether indirect interests held through related parties under common control are considered variable interests, increasing consistency of guidance for common control arrangements. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In November 2018, the FASB issued ASU 2018-18 Collaborative Arrangements (Topic 808) - Clarifying the Interaction between Topic 808 and Topic 606 . This amendment clarifies the interaction between Topic 808 ‘Collaborative Arrangements’ and Topic 606 ‘Revenue from Contracts with Customers’. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures.

SUBSIDIARIES

SUBSIDIARIES	12 Months Ended
	Dec. 31, 2018
SUBSIDIARIES [Abstract]
SUBSIDIARIES	4. SUBSIDIARIES The following table lists our significant subsidiaries and their purpose as at December 31, 2018 . Unless otherwise indicated, we own a 100% ownership interest in each of the following subsidiaries. Name Jurisdiction of Incorporation Purpose Golar LNG 2216 Corporation Marshall Islands Owns and operates Golar Arctic Golar Management Limited United Kingdom Management company Golar Management Malaysia SDN. BDH. Malaysia Vessel management company Golar Management Norway AS Norway Vessel management company Golar Management D.O.O Croatia Vessel management company Golar GP LLC – Limited Liability Company Marshall Islands Holding company Golar LNG Energy Limited Bermuda Holding company Golar Gimi Corporation Marshall Islands Owns Gimi Golar Hilli Corp. * Marshall Islands Owns Hilli Episeyo (" Hilli ") Golar Gandria N.V. Curaçao Owns and operates Golar Gandria Golar Hull M2021 Corporation Marshall Islands Leases Golar Seal** Golar Hull M2022 Corporation Marshall Islands Leases Golar Crystal** Golar Hull M2027 Corporation Marshall Islands Owns and operates Golar Bear Golar Hull M2047 Corporation Marshall Islands Leases Golar Snow** Golar Hull M2048 Corporation Marshall Islands Leases Golar Ice** Golar LNG NB10 Corporation Marshall Islands Leases Golar Glacier** Golar LNG NB11 Corporation Marshall Islands Leases Golar Kelvin** Golar LNG NB12 Corporation Marshall Islands Owns and operates Golar Frost Golar LNG NB13 Corporation Marshall Islands Leases Golar Tundra** GVS Corporation Marshall Islands Owns and operates Golar Viking Golar Shoreline LNG Limited Bermuda Holding company Golar Hilli LLC * Marshall Islands Holding company * In February 2018, Golar Hilli LLC was incorporated with Golar as sole member. In July 2018, shares in Golar Hilli Corp. (a 89% owned subsidiary of Golar Hilli LLC) were exchanged for Hilli Common Units, Series A Special Units and Series B Special Units. See note 6 for further details. ** The above table excludes mention of the lessor variable interest entities (''lessor VIEs'') that we have leased vessels from under finance leases. The lessor VIEs are wholly-owned, newly formed special purpose vehicles ("SPVs") of financial institutions. While we do not hold any equity investments in these SPVs, we have concluded that we are the primary beneficiary of these lessor VIEs and accordingly have consolidated these entities into our financial results. See note 5 for further details.

VARIABLE INTEREST ENTITIES ("VI

VARIABLE INTEREST ENTITIES ("VIE")	12 Months Ended
	Dec. 31, 2018
VARIABLE INTEREST ENTITIES [Abstract]
VARIABLE INTEREST ENTITIES (VIE)	5. VARIABLE INTEREST ENTITIES ("VIEs") As of December 31, 2018 , we leased eight vessels (December 31, 2017: seven vessels) from VIEs as part of sale and leaseback agreements, of which four were with ICBC Finance Leasing Co. Ltd, or ICBCL; one with a subsidiary of China Merchants Bank Co. Ltd, or CMBL; one with CCB Financial Leasing Corporation Limited, or CCBFL; one with a COSCO Shipping entity, or COSCO and one with a China State Shipbuilding Corporation entity, or CSSC. ICBCL Lessor VIEs Commencing in October 2014, we sold the Golar Glacier , followed by the remaining three newbuilds (the Golar Kelvin , Golar Snow and Golar Ice ) to ICBCL entities in the first quarter of 2015. The vessels were simultaneously leased back on bareboat charters for a term of ten years . We have several options to repurchase the vessels at fixed pre-determined amounts during the charter periods with the earliest date from the fifth year anniversary of commencement of the bareboat charter, and an obligation to purchase the assets at the end of the ten year lease period. CMBL Lessor VIE In November 2015, we sold the Golar Tundra to a CMBL entity and subsequently leased back the vessel on a bareboat charter for a term of ten years . We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the third year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period. CCBFL Lessor VIE In March 2016, we sold the Golar Seal to a CCBFL entity and subsequently leased back the vessel on a bareboat charter for a term of ten years. We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the fifth year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period. COSCO Lessor VIE In March 2017, we sold the Golar Crystal to a COSCO entity and subsequently leased back the vessel on a bareboat charter for a term of ten years. We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the third year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period. CSSC Lessor VIE In June 2018, we sold the Hilli to a CSSC entity and subsequently leased back the vessel on a bareboat charter for a term of ten years. We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the fifth year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period. While we do not hold any equity investments in the above SPVs, we have determined that we have a variable interest in these SPVs and that these lessor entities, that own the vessels, are VIEs. Based on our evaluation of the agreements, we have concluded that we are the primary beneficiary of these VIEs and, accordingly, these VIEs are consolidated into our financial results. We did not record any gains or losses from the sale of these vessels as they continued to be reported as vessels at their original costs in our consolidated financial statements at the time of each transaction. Similarly, the effect of the bareboat charter arrangement is eliminated upon consolidation of the SPV. The equity attributable to ICBCL, CMBL, CCBFL, COSCO and CSSC in their respective VIEs are included in non-controlling interests in our consolidated financial statements. As of December 31, 2018 and 2017 , the respective vessels are reported under "Vessels and equipment, net" in our consolidated balance sheets. The following table gives a summary of the sale and leaseback arrangements, including repurchase options and obligations as of December 31, 2018 : Vessel Effective from Sales value (in $ millions) First repurchase option (in $ millions) Date of first repurchase option Repurchase obligation at end of lease term (in $ millions) End of lease term Golar Glacier October 2014 204.0 173.8 October 2019 135.1 October 2024 Golar Kelvin January 2015 204.0 173.8 January 2020 135.1 January 2025 Golar Snow January 2015 204.0 173.8 January 2020 135.1 January 2025 Golar Ice February 2015 204.0 173.8 February 2020 135.1 February 2025 Golar Tundra November 2015 254.6 168.7 November 2018 (1) 76.4 November 2025 Golar Seal March 2016 203.0 132.8 March 2021 87.4 March 2026 Golar Crystal March 2017 187.0 97.3 March 2020 50.6 March 2027 Hilli June 2018 1,200.0 633.2 June 2023 300.0 June 2028 (1) We did not exercise the first repurchase option relating to the Golar Tundra . A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of December 31, 2018 , are shown below: (in thousands of $) 2019 2020 2021 2022 2023 2024+ Golar Glacier 17,100 17,147 17,100 17,100 17,100 12,884 Golar Kelvin 17,100 17,147 17,100 17,100 17,100 15,695 Golar Snow 17,100 17,147 17,100 17,100 17,100 15,695 Golar Ice 17,100 17,147 17,100 17,100 17,100 18,599 Golar Tundra (1)(2) 22,437 21,548 20,610 19,697 18,784 32,079 Golar Seal (2) 13,754 13,717 13,717 13,717 13,754 27,433 Golar Crystal (1) 12,441 12,335 12,175 12,050 11,907 37,601 Hilli (1) 128,418 123,526 118,800 114,075 109,463 412,055 (1) The payment obligations relating to the Golar Tundra , Golar Crystal and Hilli above include variable rental payments due under the lease based on an assumed LIBOR plus a margin. (2) The payment obligations relating to the Golar Tundra and the Golar Seal above have been prepared on the assumption that we are able to secure a replacement charter for these two vessels, to ensure continuation of these financing arrangements. Refer to note 1 for further details. The assets and liabilities of the lessor VIEs that most significantly impact our consolidated balance sheets as of December 31, 2018 and 2017 , are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli 2018 2017 Assets Total Total Restricted cash and short-term deposits (see note 14) 21,170 71,924 19,294 8 — 3,405 3,186 57,441 176,428 130,063 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 39,319 182,540 30,404 117,888 121,741 — 5,741 148,880 646,513 833,664 Long-term interest bearing debt - non-current portion (1) 114,093 — 123,267 — — 123,524 90,790 749,100 1,200,774 252,691 153,412 182,540 153,671 117,888 121,741 123,524 96,531 897,980 1,847,287 1,086,355 (1) Where applicable, these balances are net of deferred finance charges (see note 20). The most significant impact of the lessor VIEs operations on our consolidated statements of income is interest expense of $61.5 million , $37.4 million and $44.1 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. The most significant impact of the lessor VIEs cash flows on our consolidated statements of cash flows is net cash received in financing activities of $761.2 million , $51.5 million and $154.2 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. Subsequent to the sale of common units in Golar Hilli LLC (see note 6 for further information), we have retained sole control over the most significant activities and the greatest exposure to variability in residual returns and expected losses from the Hilli . Accordingly, management have concluded Hilli LLC is a VIE and that we are the primary beneficiary. The assets and liabilities of Hilli LLC that most significantly impact our consolidated balance sheet as of December 31, 2018, are as follows: (in thousands of $) Hilli LLC (2) Assets Cash and short-term deposits 85,238 Restricted cash and short-term deposits 57,441 Vessels and equipment, net 1,301,279 Other non-current assets 91,431 1,535,389 Liabilities Current portion of long-term debt and short-term debt (1) 148,880 Long-term interest bearing debt - non-current portion (1) 749,100 897,980 (1) Where applicable, these balances are net of deferred finance charges. (2) As Hilli LLC is the primary beneficiary of the Hilli Lessor VIE (see above) the Hilli LLC balances include the Hilli Lessor VIE. The most significant impact of Hilli LLC VIE's operations on our consolidated statements of operations is liquefaction services revenue of $127.6 million and realized and unrealized gain on oil derivative instrument of $16.8 million for the period July 12, 2018 to December 31, 2018. The most significant impact of lessor VIE's cash flows on our consolidated statements of cash flows is net payments of $30.3 million in financing activities for the period July 12, 2018 to December 31, 2018.

DISPOSAL OF LONG-LIVED ASSETS

DISPOSAL OF LONG-LIVED ASSETS	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
DISPOSAL OF LONG-LIVED ASSETS	6. DISPOSAL OF LONG-LIVED ASSETS 6.1 Partial disposal of the Hilli On July 12, 2018 (the "Closing Date"), we and affiliates of Keppel Shipyard Limited ("Keppel") and Black & Veatch Corporation ("B&V") (together, the "Sellers"), completed the sale ("Hilli Disposal") to Golar Partners of common units in our consolidated subsidiary Golar Hilli LLC ("Hilli LLC") (the "Hilli Common Units"), which owns Golar Hilli Corp. ("Hilli Corp"), the disponent owner of the Hilli . The Hilli Disposal resulted in the following changes to our ownership interest in our consolidated subsidiary Hilli LLC in our equity: (in thousands of $) December 31, 2018 Net loss attributable to stockholders of Golar LNG Limited (231,428 ) Transfer to the non-controlling interests: increase in Golar LNG Limited’s paid-in capital for sale of 1,096 Hilli Common Units in July 2018 304,468 Changes from net income attributable to stockholders of Golar LNG Limited and transfers to non-controlling interests 73,040 The selling price for the Hilli Disposal was $658 million , less 50% of our net lease obligations under the Hilli Facility (see note 20) on the Closing Date and working capital adjustments. On August 15, 2017, concurrently with our entry into the purchase and sale agreement for the Hilli Disposal (the "Hilli Sale Agreement"), we received a deposit from Golar Partners, which, together with accrued interest, equaled $71.9 million on the Closing Date (the "Hilli deposit"), combined with Golar Partners’ payment for its exercise of the Tundra Put Right, which, together with accrued interest, equaled $110.1 million on the Closing Date (the "Deferred Purchase Price"). We applied the Hilli Deposit, the Deferred Purchase Price and interest accrued thereon as payment for the Hilli Disposal. We entered into the Amended and Restated Limited Liability Company Agreement of Hilli LLC (the "LLC Agreement") on July 12, 2018. The ownership interests in Hilli LLC are represented by three classes of units, the Hilli Common Units, the Series A Special Units and the Series B Special Units. After the Hilli Disposal, we own: • 44.6% of the Hilli Common Units, with the remaining Hilli Common Units owned by Golar Partners, Keppel and B&V ( 50.0% , 5.0% and 0.4% , respectively); • 89.1% of the Series A Special Units, with the remaining Series A Special Units owned by Keppel and B&V ( 10.0% and 0.9% , respectively); and • 89.1% of the Series B Special Units, with the remaining Series B Special Units owned by Keppel and B&V ( 10.0% and 0.9% , respectively). We are the managing member of Hilli LLC and are responsible for all operational, management and administrative decisions relating to Hilli LLC’s business and, as a result, we continue to consolidate both Hilli LLC and Hilli Corp. All three classes of ownership interests in Hilli LLC have certain participating and protective rights. We reflect Keppel and B&V’s ownership in Hilli LLC’s Series A Special Units and Series B Special Units as non-controlling interests in our financial statements. The LLC Agreement provides that within 60 days after the end of each quarter (commencing with the quarter ending September 30, 2018), we, in our capacity as the managing member of Hilli LLC, shall determine the amount of Hilli LLC’s available cash and appropriate reserves (including cash reserves for future maintenance capital expenditures, working capital and other matters), and Hilli LLC shall make a distribution to the unitholders of Hilli LLC (the "Hilli Unitholders") of the available cash, subject to such reserves. Hilli LLC shall make distributions to the Hilli Unitholders when, as and if declared by us; provided, however, that no distributions may be made on the Hilli Common Units on any distribution date unless Series A Distributions (defined below) and Series B Distributions (defined below) for the most recently ended quarter and any accumulated Series A Distributions and Series B Distributions in arrears for any past quarter have been or contemporaneously are being paid or provided for. Series A Special Units: The Series A Special Units rank senior to the Hilli Common Units and on par with the Series B Special Units. Upon termination of the LTA, Hilli LLC has a right to redeem the Series A Special Units from legally available funds at a redemption price of $1 plus any unpaid distributions. There are no conversion features on the Series A Special Units. "Series A Distributions" reflect all incremental cash receipts by Hilli Corp during such quarter when Brent Crude prices rise above $60 per barrel with contractually defined adjustments. Series B Special Units: The Series B Special Units rank senior to the Hilli Common Units and on par with the Series A Special Units. There are no conversion or redemption features on the Series B Special Units. Incremental returns generated from future vessel expansion capacity (currently uncontracted and excluding the exercise of additional capacity under the existing LTA) include cash receipts and contractually defined adjustments. Of such vessel expansion capacity distributions ("Series B Distributions"): • holders of Series B Special Units are entitled to 95% of these distributions, and • holders of Hilli Common Units are entitled to 5% of these distributions. Hilli Common Units: Distributions attributable to Hilli Common Unitholders are not declared until any accumulated Series A Special Units and Series B Special Units distributions have been paid. As discussed above, Hilli Common Unitholders are entitled to receive a pro rata share of 5% of the vessel expansion capacity distributions. Impact of partial disposal: Hilli LLC is an entity where the economic results are allocated based on the LLC Agreement rather than relative ownership percentages. This is due to the different classes of equity within the Hilli LLC entity, as discussed above (Hilli Common Units, Series A Special Units, Series B Special Units). As the LLC Agreement is a substantive contractual arrangement that specifies the allocation of cash proceeds, management has allocated the results of the Hilli LLC entity based on this. The main assumption made in the above exercise was to make certain assumptions about the allocation of non-cash components. Specifically, the unrealized mark-to-market movement in the oil derivative instrument is allocated to the Series A Special Unit holders only as they are the only unit holders who benefit from the oil-linked revenues, and the cost of the Hilli asset is allocated between the Hilli Common Unit holders and the Series B Special Unit holders. This split follows the allocation of cash revenues associated with the capacity of the asset to the Hilli Common Unit holders and the Series B Special Unit holders. 6.2 Deconsolidation of Golar Power entities In June 2016, we entered into certain agreements forming a 50/50 joint venture, Golar Power Ltd ("Golar Power"), with investment vehicles affiliated with the private equity firm Stonepeak Infrastructure Partners ("Stonepeak"). The purpose of Golar Power is to offer integrated LNG based downstream solutions through the ownership and operation of FSRUs and associated terminal and power generation infrastructure. The transaction closed on July 6, 2016 with the receipt of net proceeds of $113 million from the disposal of 50% of our holding in the ordinary share capital of Golar Power to Stonepeak. Accordingly, effective from this date, we deconsolidated the results and net assets relating to the two vessels; the Golar Penguin and the Golar Celsius , the newbuild Golar Nanook and LNG Power Limited, which holds the rights to participate in the Sergipe Project. On the same date, we commenced equity accounting for our residual interest in Golar Power and we recorded an investment in Golar Power of $116 million , which represents the fair value of our remaining 50% holding in Golar Power's ordinary share capital. We calculated a loss on disposal of $8.5 million . The table below illustrates how the loss on loss of control has been calculated: (in thousands of $) As of July 6, 2016 Net proceeds (a) 113,000 Fair value of 50% retained investment in Golar Power (b) 116,000 Fair value of counter guarantees from Golar Power (c) 3,701 Total fair value of Golar Power 232,701 Less: Carrying value of Golar Power’s net assets (d) 236,713 Guarantees issued by Golar to Golar Power (e) 4,471 Loss on loss of control of Golar Power (8,483 ) (a) Net proceeds received for the disposal of 50% in Golar Power The table below shows the purchase consideration we received for the disposal of a 50% interest in the ordinary share capital in Golar Power that was acquired by Stonepeak: (in thousands of $) As of July 6, 2016 Consideration received from Stonepeak 116,000 Less: Fee paid in relation to the transaction (3,000 ) Net proceeds 113,000 (b) Fair value of the retained investment in Golar Power The fair value of our retained investment, being the 50% interest in the ordinary share capital in Golar Power has been recorded at $116 million . The fair value was determined with reference to the consideration of $116 million we received from Stonepeak pertaining to the 50% ordinary share capital interest they acquired. Thus given that this was negotiated between third parties, this is representative of fair value. (c) Fair value of counter guarantees from Golar Power A number of counter guarantees were entered into by Golar Power for the benefit of Golar LNG, specifically to reimburse Golar for the historic legacy debt guarantees discussed in (e) below. In aggregate, based on the agreed premiums the fair value of these counter guarantees were calculated as $3.7 million . (d) Carrying value of Golar Power's net assets The table below shows the underlying carrying value of Golar Power's net assets at the deconsolidation date: (in thousands of $) As at July 6, 2016 ASSETS Current Cash and cash equivalents 10,992 Restricted cash 15,463 Trade accounts receivable 1,474 Other receivables, prepaid expenses and accrued income 178 Short term amounts due from related parties 3,000 Inventory 952 Total current assets 32,059 Non-current Newbuildings 50,436 Vessels, net 387,261 Total assets 469,756 LIABILITIES AND STOCKHOLDERS' EQUITY Current Current portion of long-term debt 20,032 Trade accounts payable 969 Accrued expenses 21,357 Total current liabilities 42,358 Non-current Long-term debt 190,685 Total liabilities 233,043 Equity Stockholders’ equity 236,713 Total liabilities and stockholders' equity 469,756 (e) Guarantees issued by Golar to Golar Power The guarantees issued by us in respect of Golar Power and its subsidiaries were fair valued as of the deconsolidation date which amounted to a liability of $4.5 million . This comprises of the following items: (in thousands of $) As of July 6, 2016 Debt guarantees 3,283 Shipyard guarantee 1,188 Total guarantees 4,471 Debt guarantees - The debt guarantees were previously issued by Golar to third party banks in respect of certain secured debt facilities relating to Golar Power and subsidiaries. The liability which is recorded in "Other non-current liabilities" is being amortized over the remaining term of the respective debt facilities with the credit being recognized in "Other financial items". See "Transactions with Golar Power and subsidiaries" in note 28. Shipyard guarantee - Golar has provided Samsung with a guarantee of settlement in relation to the shipbuilding contract of Golar Nanook , which now forms part of Golar Power's asset base. The liability which is recorded in "Other current liabilities" is being amortized on a straight line basis until delivery of the vessel with the credit being recognized in "Other financial items". See "Transactions with Golar Power and subsidiaries" in note 28.

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
SEGMENT INFORMATION	7. SEGMENT INFORMATION We are a marine LNG infrastructure provider and a project development company. We own and operate LNG carriers, a FLNG and FSRUs and provide these services under time charters under varying periods. As of December 31, 2018 , we have completed the commissioning of our first FLNG vessel and have entered the power market in an effort to become a midstream LNG solution provider. Our reportable segments consist of the primary services each provides. Although our segments are generally influenced by the same economic factors, each represents a distinct product in the LNG industry. Segment results are evaluated based on operating income. The accounting principles for the segments are the same as for our consolidated financial statements. "Project development expenses" are allocated to each segment based on the nature of the project. Indirect general and administrative expenses are allocated to each segment based on estimated use. The split of the organization of the business into three reportable segments is based on differences in management structure and reporting, economic characteristics, customer base, asset class and contract structure. As of December 31, 2018 , we operate in the following three reportable segments: • Vessel operations – We operate and subsequently charter out vessels on fixed terms to customers. We also provide technical vessel management services for our fleet as well as the fleets of Golar Partners and Golar Power. • FLNG – In 2014, we ordered our first FLNG based on the conversion of our existing LNG carrier, the Hilli. The Hilli FLNG conversion was completed and the vessel was accepted by the customer under the LTA. In February 2019 Golar entered into an agreement with BP for the charter of a FLNG, which will be converted from our existing LNG carrier, the Gimi , for a 20-year period expected to commence in 2022. The Gimi was relocated from layup to Keppel Shipyard in early 2019 to proceed with the conversion. In July 2016, we entered into an agreement with Schlumberger B.V. ("Schlumberger") to form OneLNG, a joint venture, with the intention to offer an integrated upstream and midstream solution for the development of low cost gas reserves to LNG. As a result we report the equity in net losses of OneLNG in the FLNG segment. In May 2018, it was decided that Golar and Schlumberger will wind down OneLNG and work on FLNG projects as required on a case-by-case basis. • Power – In July 2016, we entered into certain agreements forming a 50/50 joint venture, Golar Power, with private equity firm Stonepeak. Golar Power offers integrated LNG based downstream solutions, through the ownership and operation of FSRUs and associated terminal and power generation infrastructure. December 31, 2018 December 31, 2017 December 31, 2016 (3) (in thousands of $) Vessel Operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 302,979 127,625 — — 430,604 143,537 — — — 143,537 80,257 — — — 80,257 Depreciation and amortization (65,496 ) (28,193 ) — — (93,689 ) (76,522 ) — — — (76,522 ) (72,972 ) — — — (72,972 ) Other operating expenses (231,887 ) (44,031 ) — — (275,918 ) (163,207 ) (4,365 ) — — (167,572 ) (144,816 ) (3,576 ) — — (148,392 ) Other operating gains and losses 50,740 2,749 — — 53,489 — 15,100 — — 15,100 16 — — — 16 Operating income (loss) 56,336 58,150 — — 114,486 (96,192 ) 10,735 — — (85,457 ) (137,515 ) (3,576 ) — — (141,091 ) Inter segment operating income (loss) (2) 335 — — (335 ) — 4,568 — — (4,568 ) — 275 — — (275 ) — Segment operating (loss) income 56,671 58,150 — (335 ) 114,486 (91,624 ) 10,735 — (4,568 ) (85,457 ) (137,240 ) (3,576 ) — (275 ) (141,091 ) Equity in net (losses) earnings of affiliates (138,676 ) (2,047 ) (16,913 ) — (157,636 ) 1,503 (8,153 ) (18,798 ) — (25,448 ) 37,344 — 10,534 — 47,878 Balance sheet: Total assets 2,990,506 1,555,389 266,151 (5,451 ) 4,806,595 3,025,244 1,515,463 228,696 (5,116 ) 4,764,287 3,152,311 978,614 126,534 (548 ) 4,256,911 Investment in affiliates 305,631 — 266,151 — 571,782 472,482 2,047 228,696 — 703,225 512,046 10,200 126,534 — 648,780 Capital expenditures 22,978 116,715 — — 139,693 1,349 390,552 — — 391,901 33,698 200,820 — — 234,518 (1) Eliminations required for consolidation purposes. (2) Inter segment operating income (loss) relates to management fee and charterhire revenues between the segments. (3) We no longer consider LNG trading a separate reportable segment. Given the previously reported segment information was immaterial for all periods presented, we have included these amounts within the vessel operations segment. Revenues from external customers During the year ended December 31, 2018 our vessels operated predominately within the Cool Pool and under our LTA with Perenco Cameroon S.A. ("Perenco") and Société Nationale des Hydrocarbures ("SNH"), (together, the "Customer"). In the years ended December 31, 2018 , 2017 and 2016 , revenues from the following customers accounted for over 10% of our consolidated time and voyage charter revenues: (in thousands of $) 2018 2017 2016 The Cool Pool (1) 251,070 62 % 106,302 91 % 51,075 77 % Perenco and SNH (note 8) 127,625 31 % — — % — — % An energy and logistics company 9,235 2 % 9,235 8 % 7,975 12 % (1) The 2018 Cool Pool revenue of $251.1 million includes revenue of $73.9 million that is separately disclosed in the consolidated statements of operations as from a collaborative arrangement. The balance of $177.2 million was derived from Golar vessels operating within the Cool Pool, and is included within the caption "Time and voyage charter revenues" in the consolidated statements of operations. See note 28. The above revenues exclude vessel and other management fees from Golar Partners (see note 28). Geographic data The following geographical data presents our revenues from customers and fixed assets with respect only to our FLNG, while operating under the LTA, in Cameroon. In time and voyage charters for LNG carriers (or our FSRU, operating as a LNG carrier), the charterer, not us, controls the routes of our vessels. These routes can be worldwide as determined by the charterers. Accordingly, our management, including the chief operating decision maker, do not evaluate our performance either according to customer or geographical region. (in thousands of $) 2018 2017 2016 Cameroon Liquefaction services revenue 127,625 — — Total assets 1,535,389 1,515,463 —

REVENUE

REVENUE	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue	8. REVENUE Contract assets arise when we render services in advance of receiving payment from our customers. Contract liabilities arise when the customer makes payments in advance of receiving the services. Changes in our contract balances during the period are as follows: (in thousands of $) Contract assets (1) Contract liabilities (2) Opening balance on January 1, 2018 17,245 — Payments received for services billed (14,558 ) — Services provided and billed in current period 143,670 33,763 Payments received for services billed in current period (120,975 ) — Impairment (1,006 ) — Deferred commissioning period revenue — (2,467 ) Closing balance on December 31, 2018 24,376 31,296 (1) Relates to management fee revenue and liquefaction services revenue, see a) and b) below. (2) Relates to liquefaction services revenue, see b) below. a) Management fee revenue: By virtue of an agreement to offset intercompany balances entered into between us and Golar Partners, of our total contract asset balances above: • $3.1 million is included in balance sheet line item "Amounts due from related parties" under current assets ( $7.2 million at December 31, 2017), and • $4.3 million is included in "Amounts due to related parties" under current liabilities ( $10.0 million at December 31, 2017). Refer to note 28 for further details of our management fee revenue and contract terms. b) Liquefaction services revenue: The Hilli is moored in close proximity to the Customer’s gasfields, providing liquefaction service capacity over the term of the LTA. Liquefaction services revenue recognized comprises the following amounts: Year Ended (in thousands of $) 2018 2017 Base tolling fee (1) 119,677 — Amortization of deferred commissioning period revenue (2) 2,467 — Amortization of Day 1 gain (3) 5,817 — Other (336 ) — Total 127,625 — (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel (included in "Liquefaction services revenue" in the consolidated statements of income), and at an increased rate when the oil price is greater than $60 per barrel (recognized as a derivative and included in "Realized and unrealized gain on oil derivative instrument" in the consolidated statements of income, excluded from revenue and from the transaction price). (2) Customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, of $33.8 million is considered an upfront payment for services. These amounts billed are deferred (included in "Other current liabilities" and "Other non-current liabilities" in the consolidated balance sheets) and recognized as part of "Liquefaction services revenue" in the consolidated statements of income evenly over the contract term. (3) The Day 1 gain was established when the oil derivative instrument was initially recognized in December 2017 for $79.6 million (recognized in "Other current liabilities" and "Other non-current liabilities" in the consolidated balance sheets). This amount is amortized and recognized as part of "Liquefaction services revenue" in the consolidated statements of income evenly over the contract term. We expect to recognize liquefaction services revenue related to the partially unsatisfied performance obligation at the reporting date evenly over the remaining contract term of less than eight years, including the components of transaction price described above.

IMPAIRMENT OF NON-CURRENT ASSET

IMPAIRMENT OF NON-CURRENT ASSETS	12 Months Ended
	Dec. 31, 2018
IMPAIRMENT OF LONG-TERM ASSETS [Abstract]
IMPAIRMENT OF NON-CURRENT ASSETS	9. IMPAIRMENT OF NON-CURRENT ASSETS Vessels The following table presents the market values and carrying values of nine of our vessels that we have determined to have market values that are less than their carrying values as of December 31, 2018 . However, based on the estimated future undiscounted cash flows of these vessels, which are significantly greater than the respective carrying values, no impairment was recognized. (in thousands of $) Vessel 2018 Market value (1) 2018 Carrying value Deficit Golar Arctic 76,750 134,400 57,650 Golar Seal 178,750 179,000 250 Golar Bear 182,000 183,900 1,900 Golar Frost 182,000 187,700 5,700 Golar Viking 78,250 112,300 34,050 Golar Glacier 182,500 183,500 1,000 Golar Snow 184,500 191,800 7,300 Golar Ice 184,000 192,000 8,000 Golar Kelvin 183,500 185,600 2,100 (1) Market values are determined using reference to average broker values provided by independent brokers. Broker values are considered an estimate of the market value for the purpose of determining whether an impairment trigger exists. Broker values are commonly used and accepted by our lenders in relation to determining compliance with relevant covenants in applicable credit facilities for the purpose of assessing security quality. Since vessel values can be volatile, our estimates of market value may not be indicative of either the current or future prices we could obtain if we sold any of the vessels. In addition, the determination of estimated market values may involve considerable judgment, given the illiquidity of the second-hand markets for these types of vessels. Long-lived assets The following table presents the impairment charge recognized in relation to equipment included in "Other non-current assets", acquired due to uncertainty of the future usage of this equipment: (in thousands of $) 2018 2017 2016 Impairment charge — — 1,706 Investment in affiliates In November 2018, Golar Partners announced a distribution cut which failed to translate into an improved share price. Given the failure of the share price to recover and the sustained period of the suppressed share price, we believe that the difference between the carrying value and the fair value of our equity accounted investment is no longer temporary. On December 31, 2018, we recorded an impairment charge of $149.4 million . The fair value of our investment in Golar Partners is categorized within level 2 of the fair value hierarchy. The methodology applied to arrive at the fair value was to apply a Monte Carlo Simulation model to estimate the total equity value of Golar Partners which determines the total distribution payment to all unitholders including Common, GP units and IDRs. The key inputs into the model are the valuation date share price, long term volatility curve and dividend yield of Golar Partners.

(LOSSES) GAINS ON DERIVATIVE IN

(LOSSES) GAINS ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET	12 Months Ended
	Dec. 31, 2018
OTHER FINANCIAL ITEMS, NET [Abstract]
(LOSSES) GAINS ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET	10. (LOSSES) GAINS ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET (Losses) gains on derivative instruments comprise of the following: (in thousands of $) 2018 2017 2016 Mark-to-market adjustment for interest rate swap derivatives (see note 27) 604 6,614 2,818 Mark-to-market adjustment for equity derivatives (see note 27) (30,663 ) 16,622 24,819 Mark-to-market adjustment for foreign exchange swap derivatives (1,151 ) 821 (993 ) Unrealized mark-to-market (losses) gains on Earn-Out Units (see note 19) (7,400 ) 441 — Interest income (expense) on undesignated interest rate swaps (see note 27) 8,069 (3,802 ) (10,153 ) (30,541 ) 20,696 16,491 Other financial items, net comprise of the following: (in thousands of $) 2018 2017 2016 Impairment of loan (1) — — (7,627 ) Financing arrangement fees and other costs (244 ) (677 ) (404 ) Amortization of debt guarantee 861 1,548 1,563 Foreign exchange loss on operations (1,997 ) (888 ) (1,909 ) Other (101 ) (52 ) 577 (1,481 ) (69 ) (7,800 ) (1) Given the announcement of a negative Final Investment Decision from the Douglas Channel Project consortium in 2014, we reassessed the recoverability of the loan and accrued interest receivables from the Douglas Channel LNG Assets Partnership ("DCLAP") and concluded that DCLAP would not have the means to satisfy its obligations under the loan. Accordingly, we recognized an impairment charge of $7.6 million in 2016.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
INCOME TAXES	11. INCOME TAXES The components of income tax expense (benefit) are as follows: Year ended December 31 (in thousands of $) 2018 2017 2016 Current tax expense 836 1,478 1,035 Deferred tax expense 431 27 90 Amortization of tax benefit arising on intra-group transfers of non-current assets — — (1,714 ) Total income tax expense (benefit) 1,267 1,505 (589 ) The income taxes for the years ended December 31, 2018 , 2017 and 2016 differed from the amount computed by applying the Bermuda statutory income tax rate of 0% as follows: Year ended December 31 (in thousands of $) 2018 2017 2016 Income taxes at statutory rate — — — Effect of deferred tax benefit on intra-group transfers of non-current assets — — (1,714 ) Effect of movement in deferred tax balances 431 27 90 Effect of adjustments in respect of current tax in prior periods (369 ) (5 ) (334 ) Effect of taxable income in various countries 1,205 1,483 1,369 Total tax expense (benefit) 1,267 1,505 (589 ) Jurisdictions open to examination The earliest tax year that remains subject to examination by the major taxable jurisdictions in which we operate are: UK (2017) and Norway (2015).

LOSS PER SHARE

LOSS PER SHARE	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
LOSS PER SHARE	12. LOSS PER SHARE Basic earnings (loss) per share ("EPS") is calculated with reference to the weighted average number of common shares outstanding during the year. The components of the numerator for the calculation of basic and diluted EPS are as follows: (in thousands of $) 2018 2017 2016 Net loss attributable to Golar LNG Ltd stockholders - basic and diluted (231,428 ) (179,703 ) (186,531 ) The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) 2018 2017 2016 Basic and diluted loss per share: Weighted average number of common shares outstanding 100,684 100,597 93,933 Loss per share are as follows: 2018 2017 2016 Basic and diluted $ (2.30 ) $ (1.79 ) $ (1.99 ) The effects of stock options and convertible bonds have been excluded from the calculation of diluted EPS for each of the years ended December 31, 2018 , 2017 and 2016 because the effects were anti-dilutive.

OPERATING LEASES

OPERATING LEASES	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
OPERATING LEASES	13. OPERATING LEASES Rental income The minimum contractual future revenues to be received on time charters in respect of our vessels as of December 31, 2018 , were as follows: Year ending December 31 (in thousands of $) 2019 25,851 Total 25,851 The cost and accumulated depreciation of vessels leased to third parties at December 31, 2018 and 2017 were $331.5 million and $35.6 million ; and $191.1 million and $53.6 million , respectively. Rental expense We are committed to making rental payments under operating leases. The future minimum rental payments under our non-cancellable operating leases are as follows: Year ending December 31 Total (in thousands of $) 2019 5,417 2020 3,756 2021 2,682 2022 2,425 2023 and thereafter 6,180 Total minimum lease payments 20,460 Total rental expense for operating leases was $8.2 million , $19.3 million and $29.6 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. In prior years, the Golar Grand was chartered back from Golar Partners under agreements executed at the time of its disposals to Golar Partners. The Golar Grand charter-back arrangement with Golar Partners ceased in October 2017. Total rental expense for operating leases for the year ended December 31, 2018 includes $6.1 million of minimum rental expense, $2.2 million of contingent rental expense and sublease rental income of $0.1 million .

RESTRICTED CASH AND SHORT-TERM

RESTRICTED CASH AND SHORT-TERM DEPOSITS	12 Months Ended
	Dec. 31, 2018
Restricted Cash and Investments [Abstract]
RESTRICTED CASH AND SHORT-TERM DEPOSITS	14. RESTRICTED CASH AND SHORT-TERM DEPOSITS Our restricted cash and short-term deposits balances are as follows: (in thousands of $) 2018 2017 Restricted cash relating to the total return equity swap (1) 82,863 58,351 Restricted cash in relation to the Hilli (2) 174,597 174,737 Restricted cash and short-term deposits held by lessor VIEs (3) 176,428 130,063 Restricted cash relating to the $1.125 billion debt facility (4) 17,657 33,752 Collateral on the Margin Loan Facility (5) 33,413 — Restricted cash relating to office lease 777 813 Bank guarantee 691 99 Total restricted cash and short-term deposits 486,426 397,815 Less: Amounts included in current restricted cash and short-term deposits (332,033 ) (222,265 ) Long-term restricted cash 154,393 175,550 (1) Restricted cash relating to the share repurchase forward swap refers to the collateral required by the bank with whom we entered into a total return equity swap. Collateral of 20% of the total purchase price is required and this is subsequently adjusted with reference to the Company's share price (see note 27). (2) In November 2015, in connection with the issuance of a $400 million letter of credit by a financial institution to our project partner involved in the Hilli FLNG project, we posted an initial cash collateral sum of $305.0 million to support the performance guarantee. Under the provisions of the $400 million letter of credit, the terms allow for a stepped reduction in the value of the guarantee over time and thus, conversely, a reduction in the cash collateral requirements. Effective December 19, 2017, the $400 million letter of credit reduced to $300 million . The corresponding release of $57.2 million cash collateral reduced the cash collateral requirement to $174.7 million at December 31, 2017, with no further reduction in 2018. It is expected that the letter of credit will further reduce to $250.0 million during 2019. In November 2016, after certain conditions precedent were satisfied by the Company, the letter of credit required in accordance with the signed LTA was re-issued and, with an initial expiry date of December 31, 2018, the letter of credit automatically extends, on an annual basis, until the tenth anniversary of the acceptance date of the Hilli by the charterer, unless the bank should exercise its option to exit from this arrangement by giving three months' notice prior to the annual renewal date. (3) These are amounts held by lessor VIE entities that we are required to consolidate under U.S. GAAP into our financial statements as VIEs (see note 5). (4) This refers to cash deposits required under the $1.125 billion debt facility (see note 20). The covenant requires that, on the second anniversary of drawdown under the facility, where we fall below a prescribed EBITDA to debt service ratio, additional cash deposits with the financial institution are required to be made or maintained. (5) Collateral held against the Margin Loan Facility is required to satisfy one of the mandatory prepayment events within the facility, with this having been triggered when the closing price of the Golar Partners common units pledged by us as security for the obligations under the facility fell below a defined threshold. If certain requirements are met, the facility allows for the release of the collateral (see note 20). Restricted cash does not include minimum consolidated cash balances of $50.0 million (see note 20) required to be maintained as part of the financial covenants for our loan facilities, as these amounts are included in "Cash and cash equivalents".

OTHER CURRENT ASSETS

OTHER CURRENT ASSETS	12 Months Ended
	Dec. 31, 2018
Other Assets [Abstract]
OTHER CURRENT ASSETS	15. OTHER CURRENT ASSETS (in thousands of $) 2018 2017 Prepaid expenses 4,285 3,045 Other receivables 14,435 3,002 18,720 6,047

INVESTMENTS IN AFFILIATES

INVESTMENTS IN AFFILIATES	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
INVESTMENTS IN AFFILIATES	16. INVESTMENTS IN AFFILIATES At December 31, 2018 and 2017 , we have the following participation in investments that are recorded using the equity method: 2018 2017 Golar Partners (1) 32.0 % 31.8 % Egyptian Company for Gas Services S.A.E ("ECGS") 50 % 50 % Golar Power 50 % 50 % OneLNG 51 % 51 % The Cool Pool Limited ("Pool Manager") (2) 50 % 33 % Avenir LNG Limited ("Avenir") 22.5 % — (1) As of December 31, 2018 , we held a 32.0% ( 2017 : 31.8% ) ownership interest in Golar Partners (including our 2% general partner interest) and 100% of the IDRs. (2) The Pool Manager is a Marshall Islands service company that was established in September 2015 to facilitate the joint operations under the Cool Pool. Following the exit of one participant from the pool in June 2018, our participation increased to 50% . The carrying amounts of our investments in our equity method investments as at December 31, 2018 and 2017 are as follows: (in thousands of $) 2018 2017 Golar Partners 271,160 467,097 Golar Power 266,151 228,696 OneLNG — 2,047 Avenir 28,710 — Others (1) 5,761 5,385 Equity in net assets of affiliates 571,782 703,225 1 Others largely relate to our investment in ECGS amounting to $5.3 million and $5.4 million as at December 31, 2018 and 2017 , respectively. The components of equity in net assets of non-consolidated affiliates are as follows: (in thousands of $) 2018 2017 Cost 981,196 877,810 Dividends (336,286 ) (287,263 ) Equity in net earnings of affiliates 95,458 107,553 Impairment of investment in affiliate (149,389 ) — Share of other comprehensive income of affiliates (19,197 ) 5,125 Equity in net assets of affiliates 571,782 703,225 Quoted market prices for ECGS, Golar Power and OneLNG are not available because these companies are not publicly traded. Golar Partners Golar Partners is an owner and operator of FSRUs and LNG carriers under long-term charters. Golar Partners is listed on the NASDAQ. Since the deconsolidation date of Golar Partners in December 2012, we have accounted for all our investments (Common Units, GP Units and IDRs) in Golar Partners under the equity method. The initial carrying value of our investments in Golar Partners was based on the fair value on the deconsolidation date. Subsequently the day one value was adjusted for our share of Golar Partners earnings and distributions received. On December 31, 2018, we recognized an impairment charge of $149.4 million . See note 9 for further details. Exchange of Incentive Distribution Rights "IDR Reset" On October 13, 2016, we entered into an equity exchange agreement with Golar Partners in which we reset our rights to receive cash distributions in respect of our interests in the incentive distribution rights, or Old IDRs, in exchange for the issuance of (i) New IDRs, (ii) an aggregate of 2,994,364 common units and 61,109 general partner units, and (iii) an aggregate of up to 748,592 additional common units and up to 15,278 additional general partner units that may be issued if target distributions are met ("the Earn-Out Units"). Based on the agreement, half of the Earn-Out Units ("first tranche") would vest if Golar Partners paid a distribution equal to, or greater than, $0.5775 per common unit in each of the quarterly periods ended December 31, 2016, March 31, 2017, June 30, 2017 and September 30, 2017. Having satisfied the minimum quarterly distribution in respect of these quarters, Golar Partners issued to Golar 374,295 common units and 7,639 general partner units on November 15, 2017. The New IDRs result in the minimum distribution level increasing from $0.3850 per common unit to $0.5775 per common unit. The fair value of the Old IDRs was not materially different to the fair value of all of the newly issued instruments. The agreement also required Golar Partners to pay Golar the distributions that it would have been entitled to receive on these units in respect of each of those four preceding quarters. Therefore, in connection with the issuance of the above Earn-Out Units, Golar also received $0.9 million in dividends in the prior period. The remaining Earn-Out Units ("second tranche") would be issued if Golar Partners paid a distribution equal to $0.5775 per common unit in the periods ending December 31, 2017, March 31, 2018, June 30, 2018 and September 30, 2018. Having not satisfied the minimum quarterly distribution over all of these quarters, the second tranche did not vest. In relation to the IDR Reset transaction, we applied "carry over" accounting and determined that the Earn-Out Units met the definition of a derivative. Accordingly, the overall effect of the IDR Reset on the transaction date was (i) a reclassification of the initial fair value of the derivative from "Investment in affiliates" to "Other non-current assets" of $15.0 million , and (ii) the residual carrying value of the Old IDRs (after reclassification of the derivative fair value) was reallocated across the new instruments on a relative fair value basis. As of December 31, 2017, following the issuance of the first tranche of the Earn-Out Units, the fair value of the derivative amounted to $7.4 million . The decrease in Golar Partners' quarterly distribution to $0.4042 per common unit on October 24, 2018 resulted in the Earn-Out Units not crystallizing and, accordingly, we recognized a mark-to-market loss of $7.4 million for the year ended December 31, 2018 , effectively reducing the derivative asset to $ nil . ECGS In December 2005, we entered into an agreement with the Egyptian Natural Gas Holding Company and HK Petroleum Services to establish a jointly owned company, ECGS, to develop operations in Egypt, particularly in hydrocarbon and LNG related areas. In March 2006, we acquired 0.5 million common shares in ECGS at a subscription price of $1 per share. This represents a 50% interest in the voting rights of ECGS and, in December 2011, ECGS called up its remaining share capital amounting to $7.5 million . Of this, we paid $3.75 million to maintain our 50% equity interest. As ECGS is jointly owned and operated together with other third parties, we have adopted the equity method of accounting for our 50% investment in ECGS, as we consider we have joint control. Dividends received for each of the years ended December 31, 2018 and 2017 were $ 0.2 million and $ nil , respectively. Golar Power In July 2016, we entered into certain agreements forming a 50/50 joint venture, Golar Power, with private equity firm Stonepeak. Under the terms of the shareholders' agreement in relation to the formation of the joint venture company, we disposed of the entities that own and operate Golar Penguin , Golar Celsius , newbuild Golar Nanook and LNG Power Limited to Golar Power. As a result, commencing July 6, 2016, Golar Power and its subsidiaries have been considered as our affiliates and not as controlled subsidiaries of the Company. Accordingly, with effect from July 6, 2016, our investment in Golar Power has been accounted for under the equity method of accounting. Under the shareholders' agreement, we and Stonepeak have agreed to contribute additional funding to Golar Power on a pro rata basis. During the year ended December 31, 2018 , we contributed a further $55.0 million to Golar Power as a result of this agreement. In addition, interest costs capitalized on the investment in Golar Power for the years ended December 31, 2018 and 2017 , were $ 10.5 million and $6.6 million , respectively. OneLNG On July 25, 2016 Golar and Schlumberger B.V. ("Schlumberger") entered into an agreement to form OneLNG, a joint venture, with the intention to offer an integrated upstream and midstream solution for the development of low cost gas reserves to LNG. In accordance with the joint venture and shareholders' agreement, Golar holds 51% and Schlumberger the remaining 49% of OneLNG. By virtue of substantive participation rights held by Schlumberger, we account for our investment in OneLNG under the equity method of accounting. The delays in finalizing a debt financing package for the Fortuna FLNG project, together with other capital and resource priorities, has resulted in a decision from Schlumberger to end their participation in the project. Golar and Schlumberger, as a result of this, have commenced the winding down of OneLNG and will work on FLNG projects as required on a case-by-case basis. As a result, we have written down our investment in OneLNG to $ nil as at December 31, 2018 . Pool Manager In October 2015, we entered into an LNG carrier pooling arrangement with GasLog Carriers Ltd ("GasLog") and Dynagas Ltd ("Dynagas") to market our vessels which are currently operating in the LNG shipping spot market. In June 2018, Dynagas exited the pooling arrangement. As of December 31, 2018 , the Cool Pool comprised of 16 vessels, of which eight vessels were contributed by us, six vessels by GasLog and two vessels by Golar Power. The vessel owner continues to be fully responsible for the manning and the technical management of their respective vessels. For the operation of the Cool Pool, a Marshall Islands service company ("Pool Manager") was established in September 2015. The Pool Manager is jointly owned and controlled by us and GasLog. Avenir On October 1, 2018, Avenir issued a private placement of 99 million shares at a par price of $1 per share, which was successfully completed at a subscription price of $1 per share. Of the 99 million shares placed, we subscribed for 24.8 million shares, representing an investment of $24.8 million , or 25% . The investment is part of a combined commitment of up to $182.0 million from Stolt-Nielsen Limited ("Stolt-Nielsen") (an entity affiliated with our director Niels Stolt Nielsen), Höegh LNG Holdings Limited ("Höegh") and Golar for the pursuit of opportunities in small-scale LNG, including the delivery of LNG to areas of stranded gas demand, the development of LNG bunkering services and supply to the transportation sector. The consideration of $24.8 million , was deemed less than our proportionate share of net assets acquired in Avenir, at fair value. Therefore, during the year ended December 31, 2018 we recognized negative goodwill of $3.8 million in equity in net (losses) earnings of affiliates to reflect our bargain purchase. Avenir intends to utilize the best-in-class capabilities of its anchor investors to build a global presence as the leading provider of small-scale LNG, and it will be among the first movers in this market with a fleet of small-scale LNG carriers and terminals. The market for small-scale LNG is rapidly expanding, with great potential to be realized in the off-grid power, transportation and bunkering markets because of high-margin oil-to-gas switching, policy changes and environmental benefits of consuming LNG relative to alternative fossil fuels. The forthcoming IMO 2020 regulations are one of many driving factors for increased small-scale LNG consumption, and Avenir plans to introduce safe and efficient ship-to-ship bunkering services at key strategic ports to meet and develop demand for LNG as a marine fuel. Avenir was originally formed by Stolt-Nielsen in 2017 to provide LNG to markets lacking access to LNG pipelines. Stolt-Nielsen will consolidate all its LNG activities into Avenir, including four small-scale LNG carriers currently under construction at Keppel Singmarine in Nantong, China, two small-scale LNG carriers on order from Sinopacific Offshore Engineering in Nantong, China and a 80% ownership in an LNG terminal and distribution facility under development in the Italian port of Oristano, Sardinia. Avenir plans to source and ship LNG to the terminal using small LNG carriers, and distribute the LNG in trucks and through regasification into the local gas grid. On November 8, 2018, Avenir placed a further 11 million shares, also at a subscription price of $1 per share, with a group of institutional and other professional investors and, subsequent to this placement, Stolt-Nielsen, Höegh and Golar have a 45% , 22.5% and 22.5% participation in Avenir, respectively. Avenir's shares were listed on the N-OTC with effect from November 14, 2018. Summarized financial information of the affiliated undertakings shown on a 100% basis are as follows: (in thousands of $) December 31, 2018 December 31, 2017 ECGS Golar Partners Pool Manager Golar Power OneLNG Avenir ECGS Golar Partners Pool Manager Golar Power OneLNG Balance Sheet Current assets 22,955 164,529 98,448 79,029 4,884 78,591 37,476 311,496 40,661 61,374 14,955 Non-current assets 244 2,076,288 — 955,100 — 20,840 333 2,115,875 — 713,646 — Current liabilities 11,510 323,508 98,448 285,447 8,741 1,760 25,836 180,087 40,661 60,033 10,941 Non-current liabilities 1,203 1,157,792 — 149,114 — — 1,203 1,399,683 — 174,656 — Non-controlling interests — 79,902 — 1,541 — — — 76,544 — — — Statement of Operations Revenue 30,596 346,650 346,170 78,732 7 487 44,052 433,102 159,460 7,354 — Net income (loss) 207 76,548 — (10,202 ) (6,646 ) (975 ) 1,047 144,848 — (7,899 ) (14,883 )

ASSET UNDER DEVELOPMENT

ASSET UNDER DEVELOPMENT	12 Months Ended
	Dec. 31, 2018
Extractive Industries [Abstract]
ASSET UNDER DEVELOPMENT	17. ASSET UNDER DEVELOPMENT (in thousands of $) 2018 2017 Purchase price installments — 962,709 Interest costs capitalized — 116,416 Other costs capitalized (1) 20,000 98,364 20,000 1,177,489 (1) Other capitalized costs relate to the carrying value of the vessel earmarked for conversion. In May 2014, we entered into agreements for the conversion of the Hilli to a FLNG. The primary vessel conversion contract was entered into with Keppel. The Hilli was delivered to Keppel in Singapore in September 2014 for the commencement of her conversion. On completion of the Hilli FLNG conversion and commissioning, we reclassified the total balance to "Vessels and equipment, net" in our consolidated balance sheet as of December 31, 2018 . In October 2014, we entered into agreements for the conversion of the Gimi to a FLNG. The primary vessel conversion contract was entered into with Keppel in December 2018. In February 2019, Golar entered into an agreement with BP for the charter of a FLNG unit, Gimi , to service the Greater Tortue Ahmeyim project for a 20 -year period expected to commence in 2022. The Gimi was delivered to Keppel shipyard in Singapore to undergo initial works in connection with her conversion in early 2019. Accordingly, the carrying value of the Gimi of $20.0 million has been reclassified from "Vessels and equipment, net" to "Asset under development" as of the reporting date.

VESSELS AND EQUIPMENT, NET

VESSELS AND EQUIPMENT, NET	12 Months Ended
	Dec. 31, 2018
Property, Plant and Equipment [Abstract]
VESSELS AND EQUIPMENT, NET	18. VESSELS AND EQUIPMENT, NET (in thousands of $) 2018 2017 Cost As of January 1 2,431,136 2,438,720 Additions 11,304 1,349 Transfer from asset under development (1) 1,296,431 — Transfer to asset under development (90,828 ) — Write-offs (9,995 ) (8,933 ) As of December 31 3,638,048 2,431,136 Depreciation, amortization and impairment As of January 1 (354,077 ) (284,889 ) Charge for the year (2) (93,415 ) (76,522 ) Transfer to asset under development 70,828 — Write-offs 9,995 7,334 As of December 31 (366,669 ) (354,077 ) — Net book value as at December 31 3,271,379 2,077,059 (1) On completion of the Hilli FLNG conversion and commissioning, we reclassified the total balance from "Asset under development" in our consolidated balance sheet as of December 31, 2018 . Capitalized interest costs of $148.1 million are included in the cost amounts above as of December 31, 2018 . (2) Depreciation and amortization charge for the year ended December 31, 2018 excludes $0.3 million of amortization charged to non-current assets in relation to the Cameroon License fee. Drydocking costs of $133.3 million and $37.4 million are included in the cost amounts above as of December 31, 2018 and 2017 , respectively. Accumulated amortization of those costs as of December 31, 2018 and 2017 were $26.0 million and $24.3 million , respectively. Depreciation and amortization expense for each of the years ended December 31, 2018 , 2017 and 2016 was $93.4 million , $76.5 million and $73.0 million , respectively. As at December 31, 2018 and 2017 , vessels with a net book value of $ 3,244.3 million and $2,032.7 million , respectively, were pledged as security for certain debt facilities (see note 30). As at December 31, 2018 and 2017 , included in the above amounts is office equipment with a net book value of $5.7 million and $3.9 million , respectively.

OTHER NON-CURRENT ASSETS

OTHER NON-CURRENT ASSETS	12 Months Ended
	Dec. 31, 2018
OTHER NON-CURRENT ASSETS [Abstract]
OTHER NON-CURRENT ASSETS	19. OTHER NON-CURRENT ASSETS (in thousands of $) 2018 2017 Oil derivative instrument (see note 27) 84,730 94,700 Other non-current assets (1) 40,729 37,891 Mark-to-market interest rate swaps valuation (see note 27) 6,298 10,166 OLT Offshore LNG Toscana S.p.A ("OLT–O") (2) 7,347 7,347 Derivatives - other (see note 16) — 7,400 139,104 157,504 (1) "Other non-current assets" is mainly comprised of payments made relating to long lead items ordered in preparation for the conversion of the Gimi into a FLNG vessel. As of December 31, 2018 and 2017 , the aggregate carrying value was $31.0 million . The Gimi conversion contract was executed on December 13, 2018 subsequent to the receipt of a limited Notice to Proceed from BP in relation to the Greater Tortue Ahmeyim project. (2) "Investment in OLT Offshore LNG Toscana S.p.A ("OLT-O")" refers to our investment in an Italian incorporated unlisted company which is involved in the construction, development, operation and maintenance of a FSRU terminal to be situated off the Livorno coast of Italy. In prior years, this investment was classified as a cost method investment. Following the adoption of ASU 2016-01, we have applied the measurement alternative for measuring equity investments without readily determinable fair values. As of December 31, 2018 and 2017, our investment in OLT-O was $7.3 million , representing a 2.7% interest in OLT-O’s issued share capital.

DEBT

DEBT	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
DEBT	20. DEBT (in thousands of $) 2018 2017 Total long-term and short-term debt 2,565,359 2,410,847 Less: current portion of long-term debt and short-term debt (730,257 ) (1,384,933 ) Long-term debt 1,835,102 1,025,914 The outstanding debt as of December 31, 2018 is repayable as follows: Year ending December 31 Golar debt VIE debt (1) Total debt (in thousands of $) 2019 85,225 646,959 732,184 2020 163,383 82,260 245,643 2021 21,716 82,260 103,976 2022 375,377 82,260 457,637 2023 21,716 82,260 103,976 2024 and thereafter 65,151 873,629 938,780 Total 732,568 1,849,628 2,582,196 Deferred finance charges (14,494 ) (2,343 ) (16,837 ) Total 718,074 1,847,285 2,565,359 (1) These amounts relate to certain lessor entities (for which legal ownership resides with financial institutions) that we are required to consolidate under U.S. GAAP into our financial statements as variable interest entities (see note 5). At December 31, 2018 and 2017 , our debt was as follows: (in thousands of $) 2018 2017 Maturity date Golar Arctic facility 58,300 65,600 2019 Golar Viking facility 46,875 52,083 2020 2017 Convertible bonds 353,661 340,173 2022 Margin Loan 100,000 119,125 2020 FLNG Hilli facility — 525,000 2018 Hilli shareholder loans: - Keppel loan — 44,066 2027 - B&V loan — 5,000 2027 $1.125 billion facility: - Golar Bear facility 86,200 96,975 2024/2026* - Golar Frost facility 87,532 98,474 2024/2026* Subtotal (excluding lessor VIE loans) 732,568 1,346,496 ICBCL VIE loans: - Golar Glacier facility 154,226 161,876 2018/2024** - Golar Snow facility 154,566 162,566 2018/2025** - Golar Kelvin facility 182,540 182,540 ** - Golar Ice facility 117,888 134,954 ** CMBL VIE loan: - Golar Tundra facility 121,741 198,613 2026** CCBFL VIE loan: - Golar Seal facility 123,524 143,849 2026** COSCO VIE loan: - Golar Crystal facility 97,163 104,006 2027** CSSC VIE loan: - Hilli facility 897,980 — 2028** Total debt (gross) 2,582,196 2,434,900 Deferred finance charges (16,837 ) (24,053 ) Total debt 2,565,359 2,410,847 * The commercial loan tranche matures earlier of the two dates, with the remaining balance maturing at the latter date. However, in the event that the commercial tranche is not refinanced within five years, the lenders have the option to demand repayment. In October 2018, the maturity of the commercial tranche, and consequently the option to the lenders, was extended by five years, to 2024. ** This represents the total loan facilities drawn down by subsidiaries of ICBCL, CMBL, CCBFL, COSCO and CSSC, which we consider to be VIEs. See note 5. Golar Arctic facility In December 2014, we entered into a secured loan facility for $87.5 million for the purpose of refinancing the Golar Arctic . The Golar Arctic facility bears interest at LIBOR plus a margin of 2.25% and is repayable in quarterly installments over a term of five years with a final balloon payment of $52.8 million due in December 2019. Golar Viking facility In December 2015, we entered into a $62.5 million secured loan facility, with certain lenders, to finance the Golar Viking upon repossession of the vessel from Equinox. The facility is repayable in quarterly installments over a term of five years with a final balloon payment of $37.8 million due in December 2020. This facility bears interest at LIBOR plus a margin of 2.5% . 2017 Convertible bonds On February 17, 2017, we closed a new $402.5 million senior unsecured five years 2.75% convertible bond. The conversion rate for the bonds was initially equal to 26.5308 common shares per $1,000 principal amount of the bonds. This is equivalent to an initial conversion price of $37.69 per common share, or a 35% premium on the February 13, 2017 closing share price of $27.92 . The conversion price is subject to adjustment for dividends paid. To mitigate the dilution risk of conversion to common equity, we also entered into capped call transactions costing approximately $31.2 million . The capped call transactions cover approximately 10,678,647 common shares, have an initial strike price of $37.69 , and an initial cap price of $48.86 . The cap price of $48.86 , which is a proxy for the revised conversion price, represents a 75% premium on the February 13, 2017 closing share price of $27.92 . Including the $31.2 million cost of the capped call, the all-in cost of the bond is approximately 4.3% . Bond proceeds, net of fees and the cost of the capped call, amounted to $360.2 million . On inception, we recognized a liability of $320.3 million and an equity portion of $39.9 million . During 2018, the quarterly dividends in respect of the second and third quarter results exceeded the dividend threshold and resulted in an adjustment to the initial conversion rate. The distribution of the second quarter results, of $0.125 per share, increased the conversion rate to 26.6102 . This corresponds to a conversion price of $37.58 . The distribution of the third quarter results, of $0.15 per share, further increased the conversion rate to 26.6375 . This corresponds to a conversion price of $37.54 . Margin Loan Facility We entered into a loan agreement, dated March 3, 2017, among one of our wholly-owned subsidiaries, as borrower, Golar LNG Limited, as guarantor, Citibank, N.A., as administrative agent, initial collateral agent and calculation agent, and Citibank, N.A., as lender. We refer to this as the Margin Loan Facility. Pursuant to the Margin Loan Facility Citibank, N.A. provided a loan in the amount of $150 million . The Margin Loan Facility has a term of three years , an interest rate of LIBOR plus a margin of 3.95% and is secured by our Golar Partners common units and their associated distributions, and in certain cases, cash or cash equivalents. The Margin Loan Facility contains conditions, representations and warranties, covenants (including loan to value requirements), mandatory prepayment events, facility adjustment events, events of default and other provisions customary for a facility of this nature. The loan was primarily used to pay a portion of the amounts due under our 3.75% convertible senior secured bonds due March 2017, or the Prior Convertible Bonds. Concurrently with the repayment of the Prior Convertible Bonds, the trustee for these bonds released our Golar Partners common units that had been pledged to secure them. In connection with the entry into the Margin Loan Facility, we pledged 20,852,291 Golar Partners common units as security for the obligations under the facility. This was increased to 21,226,586 as part of the amendments to the facility in 2018. During July 2018, amendments to the existing Margin Loan Facility were completed. Although most of the existing terms remain substantially unchanged, the facility will no longer amortize, remaining at $100 million until maturity. Previously the dividend cash received from the pledged Partnership shares was first used to service the interest on the loan, any excess cash was then used to prepay a portion of the principal. Under the modified agreement, any excess cash after servicing the interest will be returned to Golar. Subject to the satisfaction of certain covenants, no further principal repayments will be required ahead of loan maturity in March 2020. At December 31, 2018, collateral held against the Margin Loan Facility is required to satisfy one of the mandatory prepayment events within the facility, with this having been triggered when the closing price of the Golar Partners common units pledged by us as security for the obligations under the facility fell below a defined threshold. If certain requirements are met, the facility allows for the release of the collateral. See note 14. FLNG Hilli facility In September 2015, in connection with the conversion of the Hilli to a FLNG, we entered into agreements with a subsidiary of CSSC for a pre-delivery credit facility and post-delivery sale and leaseback financing. Hilli pre-delivery facility Under the pre-delivery credit facility, we entered into an agreement with a subsidiary of CSSC to lend us up to $700 million or 60% of the initial project budget for the conversion of the Hilli to partly finance the costs of conversion. The credit facility was non-amortizing with the principal payable at the earlier of August 30, 2018 or sale of the converted Hilli to a subsidiary of CSSC under the sale and leaseback arrangement (described below under "Hilli post-delivery sale and leaseback financing"). The facility bore interest at a fixed rate of 6.25% per annum. Upon acceptance of the Hilli in June 2018, we repaid $640.0 million on the pre-delivery credit facility and drew down $960.0 million on the post-acceptance sale and leaseback financing. Hilli post-delivery sale and leaseback financing On May 31, 2018, the Hilli completed commissioning and acceptance testing procedures, was accepted under the LTA with Perenco and SNH and is began full commercial operation. On June 24, 2018, we repaid $640.0 million on the pre-delivery credit facility and drew down $960.0 million on the post-acceptance sale and leaseback financing in relation to the FLNG Hilli facility. The proceeds of this sale and leaseback financing were used, in part, to pay off the Hilli pre-delivery financing described above. We subsequently leased back the vessel on a bareboat charter for a term of ten years. We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the fifth year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period (see note 5). Hilli shareholder loans Keppel loan In September 2014, our subsidiary, Golar GHK Lessors Limited ("GGHK"), entered into a Sale and Purchase Agreement with KSI Production Pte Ltd (''KSI''), a subsidiary of Keppel, to sell 10% of its ownership in Hilli Corp for $21.7 million . In consideration, KSI paid the equity value of the shares and acquired a portion of the loans made by GGHK to Hilli Corp. The loan amounted to $21.7 million and is shown under "Long-term debt" in our consolidated financial statements as at December 31, 2017 . The loan bore interest at 6% per annum. Installment payments of 2.5% of the value of the loan were payable on a six -monthly basis beginning 12 months after final acceptance of the FLNG with a balloon payment 120 months after final acceptance. Since September 2014 through to December 31, 2015, additional cash calls were issued to meet funding requirements relating to the conversion of the Hilli to a FLNG. However, during 2015, due to surplus cash balances it was agreed by the Hilli Corp shareholders to return an amount of surplus cash to both KSI and Golar. The amount to be returned to KSI was $9 million and resulted in a decrease in the Keppel loan by the same. Accordingly, as of December 31, 2017 , the balance outstanding under the Keppel shareholder loan was $44.1 million . This loan was converted to equity on the Closing Date of the Hilli Disposal (see note 6). B&V loan In November 2014, our subsidiary, GGHK, entered into a Sale and Purchase Agreement with Black & Veatch International Company (''B&V''), a subsidiary of Black & Veatch, to sell approximately 1% of its ownership in Hilli Corp for $5.0 million . In consideration B&V paid the equity value of the shares and acquired a portion of the loans made by GGHK to Hilli Corp. The loan amounted to $5.0 million and is shown under "Long-term debt" in our consolidated financial statements as at December 31, 2017 . The loan bore interest at 6% per annum. Installment payments of 2.5% of the value of the loan were payable on a six -monthly basis beginning 12 months after final acceptance of the FLNG with a balloon payment 120 months after final acceptance. This loan was converted to equity on the Closing Date of the Hilli Disposal (see note 6). $1.125 billion facility In July 2013, we entered into a $1.125 billion facility to initially fund eight of our newbuildings. The facility bears interest at LIBOR plus a margin. The facility is divided into three tranches, with the following general terms: Tranche Proportion of facility Term of loan from date of drawdown Repayment terms K-Sure 40% 12 years Six-monthly installments KEXIM 40% 12 years Six-monthly installments Commercial 20% 5 years Six-monthly installments, unpaid balance to be refinanced after 5 years The facility bears interest at LIBOR plus a margin of 2.10% for the K-Sure tranche of the facility and 2.75% for both the KEXIM and commercial tranche of the loan. The K-Sure tranche is funded by a consortium of lenders, of which 95% is guaranteed by a Korean Trade Insurance Corporation (or K-Sure) policy; the KEXIM tranche is funded by the Export Import Bank of Korea (or KEXIM). Repayments under the K-Sure and KEXIM tranches are due semi-annually with a 12 year repayment profile. The commercial tranche is funded by a syndicate of banks and is for a term of five years from date of drawdown with a final balloon payment depending on drawdown dates for each respective vessel. In the event the commercial tranche is not refinanced prior to the end of the five years, both K-Sure and KEXIM have an option to demand repayment of the balances outstanding under their respective tranches. In October 2018, the term of the commercial tranche, and consequently the option to K-Sure and KEXIM, was extended by 5 years. The facility is further divided into vessel-specific tranches dependent upon delivery and drawdown, with each borrower being the subsidiary owning the respective vessel. As of December 31, 2018 , the aggregate balance of the facility was $173.7 million and relates to two of our vessels: the Golar Bear and the Golar Frost . However, we continue to guarantee the debt relating to the Golar Celsius and the Golar Penguin that was assumed by Golar Power in connection with the formation transaction in 2016 (see note 6). Lessor VIE debt The following loans relate to our lessor VIE entities, including ICBCL, CMBL, CCBFL, COSCO and CSSC, that we consolidate as variable interest entities ("VIEs"). Although we have no control over the funding arrangements of these entities, we consider ourselves the primary beneficiary of these VIEs and we are therefore required to consolidate these loan facilities into our financial results. See note 5 for additional information. ICBCL VIE loans Golar Glacier facility In October 2014, the SPV, Hai Jiao 1401 Limited, which owns the Golar Glacier , entered into secured financing agreements for $184.8 million consisting of senior and junior loan facilities which are denominated in USD. The senior loan facility of $153 million is a 10 year non-recourse loan provided by ICBC Brussels, with first priority lien on the Golar Glacier . The senior loan facility bears interest at LIBOR plus a margin and is repayable in semi-annual installments with a balloon payment on maturity. The short-term junior loan facility of $31.8 million is provided by ICBCIL Finance Co., a related party of ICBCL. The junior loan facility bears interest at 6% and is repayable on demand. Golar Snow facility In January 2015, the SPV, Hai Jiao 1402 Limited, which owns the Golar Snow , entered into secured financing agreements for $182.6 million consisting of senior and junior loan facilities which are denominated in USD. The senior loan facility of $160.0 million is a 10 year non-recourse loan provided by ICBC Brussels, with a first priority lien on the Golar Snow . The senior loan facility bears interest at LIBOR plus a margin and is repayable in semi-annual installments with a balloon payment on maturity. The short-term junior loan facility of $22.6 million is provided by ICBCIL Finance Co., a related party of ICBCL. The junior loan facility bears interest at 6% and is repayable on demand. Golar Kelvin facility In January 2015, the SPV, Hai Jiao 1405 Limited, which owns the Golar Kelvin , entered into a secured financing agreement for $182.5 million . The loan facility is provided by ICBCIL Finance Co., a related party of ICBCL. The loan facility is denominated in USD, bears interest at 6% and is repayable on demand. Golar Ice facility In February 2015, the SPV, Hai Jiao 1406 Limited, which owns the Golar Ice , entered into a secured financing agreement for $172.0 million . The loan facility is provided by Skysea Malta Capital Company Limited, a related party of ICBCL. The loan facility is denominated in USD, bears interest at 2.78% and is repayable on demand. CMBL VIE loan - Golar Tundra facility In November 2015, the SPV, Sea 24 Leasing Co Ltd, which owns the Golar Tundra , entered into a secured financing agreement. The loan facility is denominated in USD, bears interest at LIBOR plus a margin and was repayable in 2016. In April 2016, Sea 24 Leasing Co Ltd refinanced its debt facilities and entered into long-term debt facilities (the "Tundra Lessor VIE Debt facilities"). The Tundra Lessor VIE Debt facilities bear interest at LIBOR plus a margin and are repayable as balloon payments on maturity. A pre-condition of the Golar Tundra lease financing with CMBL is for the FSRU to be employed under an effective charter. The termination of the WAGL charter by us means that we now have to find a replacement charter by June 30, 2019 or we could be required to refinance the FSRU. As a result, we have classified the Golar Tundra facility as short-term debt as of December 31, 2018 . CCBFL VIE loan - Golar Seal facility In March 2016, the SPV, Compass Shipping 1 Corporation Limited, which owns the Golar Seal , entered into a long-term loan facility for $162.4 million . The loan facility is denominated in USD, is a 10 year loan, bears interest at 3.5% and is repayable in quarterly installments with a balloon payment on maturity. COSCO VIE loan - Golar Crystal facility In March 2017, the SPV, Oriental Fleet LNG 01 Limited, which owns the Golar Crystal , obtained an internal loan from its parent company, COSCO Shipping, to fund the purchase of the Golar Crystal . The internal loan bore no interest and was repayable on demand. In April 2018, Oriental Fleet LNG 01 Limited, entered into a long-term loan facility for $101.0 million . The loan facility is provided by a related party of COSCO Shipping. The loan facility is denominated in USD, is a 10 year loan, limited to the term of the bareboat charter, bears interest at LIBOR plus a margin and is repayable in monthly installments with a balloon payment on maturity. CSSC VIE loan - Hilli facility In June 2018, the SPV, Fortune Lianjiang Shipping S.A., which owns the Hilli , entered into a secured financing agreement for $840.0 million . This loan facility is a 10 year non-recourse loan denominated in USD, bears interest at LIBOR plus a margin and is repayable in quarterly installments with a balloon payment on maturity. In addition to this facility, the SPV entered into an internal loan with CSSC for $120.0 million . This loan bears no interest and is repayable on demand. Debt restrictions Certain of our debts are collateralized by ship liens and, in the case of some debt, pledges of shares by each guarantor subsidiary. The existing financing agreements impose operating and financing restrictions which may significantly limit or prohibit, among other things, our ability to incur additional indebtedness, create liens, sell capital shares of subsidiaries, make certain investments, engage in mergers and acquisitions, purchase and sell vessels, enter into time or consecutive voyage charters or pay dividends without the consent of the lenders. In addition, lenders may accelerate the maturity of indebtedness under financing agreements and foreclose upon the collateral securing the indebtedness upon the occurrence of certain events of default, including a failure to comply with any of the covenants contained in the financing agreements. Many of our debt agreements contain certain covenants, which require compliance with certain financial ratios. Such ratios include current assets: liabilities and minimum net worth and minimum free cash restrictions. With regards to cash restrictions, we have covenanted to retain at least $50.0 million of cash and cash equivalents on a consolidated group basis. In addition, as of December 31, 2018 there are cross default provisions in certain of our and Golar Partners' and Golar Power's loan and lease agreements. In addition to lien security, some of our debt is also collateralized through pledges of equity shares by our guarantor subsidiaries. As of December 31, 2018, we were in compliance with all our covenants under our various loan agreements.

ACCRUED EXPENSES

ACCRUED EXPENSES	12 Months Ended
	Dec. 31, 2018
Payables and Accruals [Abstract]
ACCRUED EXPENSES	21. ACCRUED EXPENSES (in thousands of $) 2018 2017 Vessel operating and drydocking expenses 24,041 10,978 Administrative expenses 11,042 9,572 Interest expense 97,688 84,249 Current tax payable 463 1,096 133,234 105,895 Vessel operating and drydocking expense related accruals are composed of vessel operating expenses such as crew wages, vessel supplies, routine repairs, maintenance, drydocking, lubricating oils and insurances. Administrative expenses related accruals are comprised of general overhead including personnel costs, legal and professional fees, costs associated with project development, property costs and other general expenses.

OTHER CURRENT LIABILITIES

OTHER CURRENT LIABILITIES	12 Months Ended
	Dec. 31, 2018
OTHER CURRENT LIABILITIES [Abstract]
OTHER CURRENT LIABILITIES	22. OTHER CURRENT LIABILITIES (in thousands of $) 2018 2017 Deferred operating cost and charterhire revenue 8,206 1,044 Mark-to-market foreign exchange swaps valuation (see note 27) 1,322 223 Mark-to-market equity swaps valuation (see note 27) 70,804 40,141 Day 1 gain deferred revenue - current portion (see note 23) 9,950 7,463 Dividends payable 16,762 5,032 Other (1) 14,485 8,379 121,529 62,282 (1) This includes amounts owed to Keppel and B&V in relation to the Hilli Disposal.

OTHER NON-CURRENT LIABILITIES

OTHER NON-CURRENT LIABILITIES	12 Months Ended
	Dec. 31, 2018
OTHER LONG-TERM LIABILITIES [Abstract]
OTHER NON-CURRENT LIABILITIES	23. OTHER NON-CURRENT LIABILITIES (in thousands of $) 2018 2017 Day 1 gain deferred revenue (1) 63,834 72,138 Deferred commissioning period revenue (2) 27,076 — Pension obligations (see note 24) 32,972 37,537 Guarantees issued to Golar Partners and Golar Power (see note 28) 14,770 11,429 Other (3) 6,912 11,444 145,564 132,548 (1) This represents the corresponding liability upon recognition of the LTA derivative asset. This deferred gain is amortized and recognized as part of "Liquefaction services revenue" in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli . The initial amount recognized was $79.6 million , of which $63.8 million is non-current at December 31, 2018 . The current portion of the Day 1 gain deferred revenue is included in "Other current liabilities" (see note 22). (2) This represents customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, which is considered an upfront payment for services. These amounts billed are recognized as part of "Liquefaction services revenue" in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli . The initial amount recognized was $33.8 million , of which $27.1 million is non-current at December 31, 2018 . The current portion of Deferred commissioning period billing is included in "Other current liabilities" (see note 22). (3) Included in "Other" is an asset retirement obligation of $4.4 million and $9.8 million for the years ended December 31, 2018 and 2017, respectively. The reduction of $5.4 million in the current year is as a result of a change in the estimated date on which the obligation will be settled, which resulted in a decrease of $5.6 million in the provision, partially offset by $0.2 million of accretion recognized for the current year ended December 31, 2018 . The corresponding asset of $4.4 million is recorded within vessels and equipment, net (see note 18).

PENSIONS

PENSIONS	12 Months Ended
	Dec. 31, 2018
Retirement Benefits [Abstract]
PENSIONS	24. PENSIONS Defined contribution scheme We operate a defined contribution scheme. The pension cost for the period represents contributions payable by us to the scheme. The charge to net income for the years ended December 31, 2018 , 2017 and 2016 was $1.9 million , $1.7 million and $1.3 million , respectively. Defined benefit schemes We have two defined benefit pension plans both of which are closed to new entrants but still cover certain of our employees. Benefits are based on the employee's years of service and compensation. Net periodic pension plan costs are determined using the Projected Unit Credit Cost method. Our plans are funded by us in conformity with the funding requirements of the applicable government regulations. Plan assets consist of both fixed income and equity funds managed by professional fund managers. We use December 31 as a measurement date for our pension plans. The components of net periodic benefit costs are as follows: (in thousands of $) 2018 2017 2016 Service cost 250 313 302 Interest cost 1,687 1,901 2,051 Expected return on plan assets (926 ) (843 ) (806 ) Recognized actuarial loss 1,392 1,182 1,060 Net periodic benefit cost 2,403 2,553 2,607 The estimated net loss for the defined benefit pension plans that will be amortized from accumulated other comprehensive income into net periodic pension benefit cost during the year ended December 31, 2018 is $1.4 million ( 2017 : $1.2 million ). The change in benefit obligation and plan assets and reconciliation of funded status as of December 31 are as follows: (in thousands of $) 2018 2017 Reconciliation of benefit obligation: Benefit obligation at January 1 51,171 50,376 Service cost 250 313 Interest cost 1,687 1,901 Actuarial (gain)/ loss (3,265 ) 873 Foreign currency exchange rate changes (599 ) 1,008 Benefit payments (3,151 ) (3,300 ) Benefit obligation at December 31 46,093 51,171 The accumulated benefit obligation at December 31, 2018 and 2017 was $45.3 million and $50.2 million , respectively. (in thousands of $) 2018 2017 Reconciliation of fair value of plan assets: Fair value of plan assets at January 1 13,634 12,503 Actual (loss)/ return on plan assets (249 ) 1,039 Employer contributions 3,617 2,316 Foreign currency exchange rate changes (730 ) 1,076 Benefit payments (3,151 ) (3,300 ) Fair value of plan assets at December 31 13,121 13,634 (in thousands of $) 2018 2017 Projected benefit obligation (46,093 ) (51,171 ) Fair value of plan assets 13,121 13,634 Unfunded status (1) (32,972 ) (37,537 ) Employer contributions and benefits paid under the pension plans include $3.6 million (2017: $2.3 million ) paid from employer assets for the year ended December 31, 2018 . (1) Our plan comprises two schemes. The details of these schemes are as follows: December 31, 2018 December 31, 2017 (in thousands of $) UK Scheme Marine Scheme Total UK Scheme Marine Scheme Total Projected benefit obligation (9,818 ) (36,275 ) (46,093 ) (11,654 ) (39,517 ) (51,171 ) Fair value of plan assets 12,291 830 13,121 12,968 666 13,634 Funded (unfunded) status at end of year 2,473 (35,445 ) (32,972 ) 1,314 (38,851 ) (37,537 ) The fair value of our plan assets, by category, as of December 31, 2018 and 2017 were as follows: (in thousands of $) 2018 2017 Equity securities 12,291 9,921 Debt securities — 3,047 Cash 830 666 13,121 13,634 The amounts recognized in accumulated other comprehensive income consist of: (in thousands of $) 2018 2017 Net actuarial loss (see note 26) 9,218 12,799 The actuarial loss recognized in other comprehensive income is net of tax of $0.4 million , $0.3 million , and $0.0 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. The asset allocation for our Marine scheme at December 31, 2018 and 2017 , by asset category are as follows: Marine scheme 2018 (%) 2017 (%) Cash 100 10,000 Total 100 100 The asset allocation for our UK scheme at December 31, 2018 and 2017 , by asset category are as follows: UK scheme 2018 (%) 2017 (%) Equity 100 76.5 Bonds — 23.5 Total 100 100 Our investment strategy is to balance risk and reward through the selection of professional investment managers and investing in pooled funds. We are expected to make the following contributions to the schemes during the year ended December 31, 2019, as follows: (in thousands of $) UK scheme Marine scheme Employer contributions 510 2,900 We are expected to make the following pension disbursements as follows: (in thousands of $) UK scheme Marine scheme 2019 330 3,000 2020 410 3,000 2021 535 3,000 2022 355 3,000 2023 370 3,000 2024 - 2028 2,310 12,500 The weighted average assumptions used to determine the benefit obligation for our plans for the years ended December 31 are as follows: 2018 2017 Discount rate 3.90 % 3.40 % Rate of compensation increase 2.20 % 2.32 % The weighted average assumptions used to determine the net periodic benefit cost for our plans for the years ended December 31 are as follows: 2018 2017 Discount rate 3.40 % 3.87 % Expected return on plan assets 6.75 % 6.75 % Rate of compensation increase 2.32 % 2.38 % The overall expected long-term rate of return on assets assumption used to determine the net periodic benefit cost for our plans for the years ended December 31, 2018 and 2017 is based on the weighted average of various returns on assets using the asset allocation as at the beginning of 2018 and 2017 . For equities and other asset classes, we have applied an equity risk premium over ten year governmental bonds.

SHARE CAPITAL AND SHARE OPTIONS

SHARE CAPITAL AND SHARE OPTIONS	12 Months Ended
	Dec. 31, 2018
SHARE CAPITAL AND SHARE OPTIONS [Abstract]
SHARE CAPITAL AND SHARE OPTIONS	25. SHARE CAPITAL AND SHARE OPTIONS Our ordinary shares are listed on the Nasdaq Stock Exchange. As at December 31, 2018 and 2017 , our authorized and issued share capital is as follows: Authorized share capital: (in thousands of $, except per share data) 2018 2017 150,000,000 (2017: 150,000,000) common shares of $1.00 each 150,000 150,000 Issued share capital: (in thousands of $, except per share data) 2018 2017 101,302,404 (2017: 101,118,289) outstanding issued common shares of $1.00 each 101,303 101,119 We issued 184,115 and 38,000 common shares upon the exercise of stock options for the years ended December 31, 2018 and 2017 , respectively. Contributed surplus As at December 31, 2018 and 2017 we had contributed surplus of $200 million . Contributed surplus is capital that can be returned to stockholders without the need to reduce share capital, thereby giving Golar greater flexibility when it comes to declaring dividends. Treasury shares In November 2014, our board of directors approved a new share repurchase program under which we may repurchase up to 5% of Golar's outstanding stock over a two -year period, which is now closed. As at December 31, 2018 and 2017 , we repurchased 0.5 million shares for a consideration of $20.5 million and were party to a Total Return Swap, or TRS, indexed to 3.0 million of Golar's shares at an average price of $45.01 . There is at present no obligation for us to purchase any shares from the counterparty. Share options In February 2002, our board of directors approved the Golar LNG Limited Share Option Scheme ("Golar Scheme"). The Golar Scheme permits the board of directors, at its discretion, to grant options and to acquire shares in the Company to employees, non-employees and directors of the Company or its subsidiaries. Options granted under the scheme will vest at a date determined by the board at the date of the grant. The options granted under the plan to date have five year terms and vest equally over a period of three to four years. There is no maximum number of shares authorized for awards of equity share options, and either authorized unissued shares or treasury shares in the Company may be used to satisfy exercised options. The Golar LNG Limited Long Term Incentive Plan ("LTIP") was adopted by our board of directors, effective as of October 24, 2017. The maximum aggregate number of common shares that may be delivered pursuant to any and all awards under the Company’s LTIP shall not exceed 3,000,000 common shares, subject to adjustment due to recapitalization or reorganization as provided under the LTIP. The LTIP allows for grants of (i) share options, (ii) share appreciation rights, (iii) restricted share awards (iv) share awards, (v) other share-based awards, (vi) cash awards, (vii) dividend equivalent rights, (viii) substitute awards and (ix) performance-based awards, or any combination of the foregoing as determined by the board of directors or nominated committee in its sole discretion. Either authorized unissued shares or treasury shares (if there are any) in the Company may be used to satisfy exercised options. During 2018 and 2017 , the Company granted individuals 0.5 million and 0.4 million share options, respectively. In 2017, the Company extended the life of 95,138 share options to September 30, 2018. The options were originally awarded from 2009 to 2011. Incremental compensation cost of $0.6 million was recognized in the year ended December 31, 2017 , representing the excess of the fair value of the options at modification date over the original fair value at grant date. As at December 31, 2018 , 2017 and 2016 , the number of options outstanding in respect of Golar shares was 3.8 million , 4.0 million and 3.8 million , respectively. The fair value of each option award is estimated on the grant date or modification date using the Black-Scholes option pricing model. The weighted average assumptions as at grant date are noted in the table below: 2018 2017 2016 Risk free interest rate 2.5 % 1.8 % 1.8 % Expected volatility of common stock 62.5 % 54.5 % 55.0 % Expected dividend yield 0.0 % 0.0 % 0.0 % Expected term of options (in years) 3.6 years 3.8 years 5.0 years The assumption for expected future volatility is based primarily on an analysis of historical volatility of our common stock. Where the criteria for using the simplified method are met, we have used this method to estimate the expected term of options based on the vesting period of the award that represents the period of time options granted are expected to be outstanding. Under the simplified method, the mid-point between the vesting date and the maximum contractual expiration date is used as the expected term. Where the criteria for using the simplified method are not met, we used the contractual term of the options of five years. The dividend yield has been estimated at 0.0% as the exercise price of the options are reduced by the value of dividends, declared and paid on a per share basis. A summary of option activity as at December 31, 2018 is presented below: (in thousands of $, except per share data) Shares (in '000s) Weighted average exercise price Weighted average remaining contractual term (years) Options outstanding at December 31, 2017 4,017 $ 37.92 3.0 Exercised during the year (184 ) $ 14.60 Forfeited during the year (521 ) $ 45.06 Lapsed during the year (15 ) $ 31.46 Granted during the year 508 $ 27.20 Options outstanding at December 31, 2018 3,805 $ 36.16 2.4 Options exercisable at: December 31, 2018 2,320 $ 39.02 1.96 December 31, 2017 1,139 $ 37.92 2.53 December 31, 2016 108 $ 2.84 0.83 The exercise price of all options is reduced by the amount of dividends declared and paid; the above figures for options granted, exercised and forfeited show the average of the prices at the time of granting, exercising and forfeiting of the options, and for options outstanding at the beginning and end of the year, the average of the reduced option prices is shown. As at December 31, 2018 , 2017 and 2016, the aggregate intrinsic value of share options that were both outstanding and exercisable was $ nil as the exercise price was higher than the market value of the share options at year end. Year ended December 31 In $'000 2018 2017 2016 Intrinsic value of share options exercised 2,621 286 1,326 Total fair value of share options fully vested in the year 16,623 13,601 113 Compensation cost recognized in the consolidated statement of operations 11,748 8,777 5,830 Share options cost capitalized* 421 1,823 822 * These costs have been capitalized as part of the cost of the conversion of the Hilli, representing share options awarded to employees directly involved in the conversion. As of December 31, 2018 , the total unrecognized compensation cost amounting to $11.3 million relating to options outstanding is expected to be recognized over a weighted average period of 1.5 years .

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS	12 Months Ended
	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
ACCUMULATED OTHER COMPREHENSIVE LOSS	26. ACCUMULATED OTHER COMPREHENSIVE LOSS Accumulated Other Comprehensive Loss As at December 31, 2018 , 2017 and 2016 , our accumulated other comprehensive loss balances consisted of the following components: Pension and post retirement benefit plan adjustments Share of affiliates comprehensive (loss) income Total accumulated comprehensive (loss) income Balance at December 31, 2015 (12,400 ) (192 ) (12,592 ) Other comprehensive (loss) income (556 ) 3,606 3,050 Balance at December 31, 2016 (12,956 ) 3,414 (9,542 ) Other comprehensive income 157 1,616 1,773 Balance at December 31, 2017 (12,799 ) 5,030 (7,769 ) Other comprehensive income (loss) 3,581 (24,324 ) (20,743 ) Balance at December 31, 2018 (9,218 ) (19,294 ) (28,512 )

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
FINANCIAL INSTRUMENTS	27. FINANCIAL INSTRUMENTS Interest rate risk management In certain situations, we may enter into financial instruments to reduce the risk associated with fluctuations in interest rates. We have entered into swaps that convert floating rate interest obligations to fixed rates, which from an economic perspective, hedge the interest rate exposure. We do not hold or issue instruments for speculative or trading purposes. The counterparties to such contracts are major banking and financial institutions. Credit risk exists to the extent that the counterparties are unable to perform under the contracts; however we do not anticipate non-performance by any of our counterparties. We manage our debt portfolio with interest rate swap agreements in U.S. dollars to achieve an overall desired position of fixed and floating interest rates. Historically, we hedge accounted for certain of our interest rate swap arrangements designated as cash flow hedges. The net gains and losses had been reported in a separate component of accumulated other comprehensive income to the extent the hedges were effective. The amount recorded in accumulated other comprehensive income would have subsequently been reclassified into earnings in the same period as the hedged items affected earnings. However, since 2015, we have ceased hedge accounting for any of our derivatives. As of December 31, 2018 and 2017 , we were party to the following interest rate swap transactions involving the payment of fixed rates in exchange for LIBOR as summarized below: Instrument (in thousands of $) Year end Notional value Maturity dates Fixed interest rates Interest rate swaps * : Receiving floating, pay fixed 2018 950,000 2019/ 2021 1.23% to 1.94% Receiving floating, pay fixed 2017 1,250,000 2018/ 2021 1.13% to 1.94% * This excludes any interest rate swap agreements designated and qualifying cash flow hedges in our equity method investments. Foreign currency risk The majority of the vessels' gross earnings are receivable in U.S. dollars. The majority of our transactions, assets and liabilities are denominated in U.S. dollars, our functional currency. However, we incur expenditure in other currencies. There is a risk that currency fluctuations will have a negative effect on the value of our cash flows. Commodity price risk A derivative asset, representing the fair value of the estimated discounted cash flows of payments due as a result of the Brent Crude price moving above the contractual floor of $60.00 per barrel over the contract term, was recognized in December 2017 following the effectiveness of the LTA. Golar bears no downside risk should the Brent Crude price move below $60.00 . Equity price risk Our Board of Directors have approved a share repurchase scheme, which is being partly financed through the use of total return swap or equity swap facilities with third party banks, indexed to our own shares. We carry the risk of fluctuations in the share price of those acquired shares. The banks are compensated at their cost of funding plus a margin. As at December 31, 2018 , the counterparty to the equity swap transactions had acquired 3.0 million shares in the Company at an average price of $45.01 . In addition, we entered into a forward contract for the acquisition of 107,000 shares in Golar Partners at an average price of $20.53 . The effect of our total return swap facilities in our consolidated statement of operations as at December 31, 2018 is a loss of $30.7 million . There is, at present, no obligation for us to purchase any shares from the counterparty. In addition to the above equity swap transactions linked to our own securities, we may, from time to time, enter into short-term equity swap arrangements relating to securities of other companies. Fair values of financial instruments We recognize our fair value estimates using a fair value hierarchy based on the inputs used to measure fair value. The fair value hierarchy has three levels based on reliability of inputs used to determine fair value as follows: Level 1: Quoted market prices in active markets for identical assets and liabilities; Level 2: Observable market-based inputs or unobservable inputs that are corroborated by market data; and Level 3: Unobservable inputs that are not corroborated by market data. There have been no transfers between different levels in the fair value hierarchy during the year. The carrying value and fair value of our financial instruments at December 31, 2018 and 2017 are as follows: 2018 2018 2017 2017 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-derivatives: Cash and cash equivalents Level 1 217,835 217,835 214,862 214,862 Restricted cash and short-term deposits Level 1 486,426 486,426 397,815 397,815 Current portion of long-term debt and short-term debt (1)(2) Level 2 (732,184 ) (732,184 ) (1,393,229 ) (1,393,229 ) Long-term debt – convertible bonds (2) Level 2 (353,661 ) (373,029 ) (340,173 ) (430,361 ) Long-term debt (2) Level 2 (1,496,351 ) (1,496,351 ) (701,498 ) (701,498 ) Derivatives: Oil derivative instrument (6) Level 2 84,730 84,730 94,700 94,700 Interest rate swaps asset (3) Level 2 10,770 10,770 10,166 10,166 Foreign exchange swaps asset (3) Level 2 — — 51 51 Foreign exchange swaps liability (3) Level 2 (1,322 ) (1,322 ) (223 ) (223 ) Total return equity swap liability (3)(4) Level 2 (70,804 ) (70,804 ) (40,141 ) (40,141 ) Earn-Out Units asset (5) Level 2 — — 7,400 7,400 (1) The carrying amounts of our short-term debts and loans receivable approximate their fair values because of the near term maturity of these instruments. (2) Our debt obligations are recorded at amortized cost in the consolidated balance sheets. The amounts presented in the table, are gross of the deferred charges amounting to $ 16.8 million and $ 24.1 million at December 31, 2018 and December 31, 2017 , respectively. (3) The fair value of certain derivative instruments is the estimated amount that we would receive or pay to terminate the agreements at the reporting date, taking into account current interest rates, foreign exchange rates, closing quoted market prices and our creditworthiness and that of our counterparties. (4) The fair value of total return equity swaps is calculated using the closing prices of the underlying listed shares, dividends paid since inception and the interest rate charged by the counterparty. (5) The Earn-Out Units were issued to Golar in connection with the IDR Reset transaction between Golar and Golar Partners in October 2016. In October 2018, Golar Partners reduced their quarterly distribution and, as such, the fair value of the Earn-Out Units was written down to $ nil . See note 16. (6) The fair value of the oil derivative instrument was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA. Significant inputs used in the valuation of the oil derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The following methods and assumptions were used to estimate the fair value of each class of financial instrument: • The carrying values of trade accounts receivable, trade accounts payable, accrued liabilities and working capital facilities approximate fair values because of the near term maturity of these instruments. • The carrying value of cash and cash equivalents, which are highly liquid, is a reasonable estimate of fair value. • The carrying value of restricted cash and short-term deposits is considered to be equal to the estimated fair value because of their near term maturity. • The estimated fair value for the liability component of the unsecured convertible bonds is based on the quoted market price as at the balance sheet date. • The estimated fair values for both the floating long-term debt and short-term debt to a related party are considered to be equal to the carrying value since they bear variable interest rates, which are adjusted on a quarterly or six-monthly basis. • The fair value measurement of a liability must reflect the non-performance of the entity. Therefore, the impact of our credit worthiness has also been factored into the fair value measurement of the derivative instruments in a liability position. • The fair value of the Earn-Out Units was determined using a Monte-Carlo simulation method. This simulation was performed within the Black Scholes option pricing model then solved via an iterative process by applying the Newton-Raphson method for the fair value of the Earn-Out Units, such that the price of a unit output by the Monte-Carlo simulation equaled the price observed in the market. The method took into account the historical volatility, dividend yield as well as the share price of the Golar Partners common units as of the IDR Reset date and at balance sheet date. • The fair value of the oil derivative instrument was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA. Significant inputs used in the valuation of the oil derivative instrument include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. • The credit exposure of interest rate swap agreements is represented by the fair value of contracts with a positive value at the end of each period, reduced by the effects of master netting arrangements. It is our policy to enter into master netting agreements with counterparties to derivative financial instrument contracts, which give us the legal right to discharge all or a portion of the amounts owed to the counterparty by offsetting them against amounts that the counterparty owes to us. • Our pension plan assets are primarily invested in funds holding equity and debt securities, which are valued at quoted market price. These plan assets are classified within Level 1 of the fair value hierarchy (see note 24). The following table summarizes the fair value of our derivative instruments on a gross basis (none of which have been designated as hedges) recorded in our consolidated balance sheets as of December 31, 2018 and 2017: Balance sheet classification 2018 2017 (in thousands of $) Asset derivatives Oil derivative instrument Other non-current assets 84,730 94,700 Earn-Out Units asset Other non-current assets — 7,400 Interest rate swaps Other current and non-current assets 10,770 10,166 Foreign exchange swaps Other non-current assets — 51 Total asset derivatives 95,500 112,317 Liability derivatives Foreign exchange swaps Other current liabilities 1,322 223 Total return equity swap Other current liabilities 70,804 40,141 Total liability derivatives 72,126 40,364 We have elected not to offset the fair values of derivative assets and liabilities executed with the same counterparty that are generally subject to enforceable master netting arrangements. However, if we were to offset and record the asset and liability balances of derivatives on a net basis, the amounts presented in our consolidated balance sheets as of December 31, 2018 and 2017 would be adjusted as detailed in the following table: 2018 2017 Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount (in thousands of $) Total asset derivatives 10,770 — 10,770 10,166 — 10,166 The total return equity swap has a credit arrangement that requires us to provide cash collateral equaling 20% of the initial purchase price and to subsequently post additional cash collateral that corresponds to any further unrealized loss. As at December 31, 2018 cash collateral amounting to $82.9 million has been provided (see note 14). Concentrations of risk There is a concentration of credit risk with respect to cash and cash equivalents and restricted cash to the extent that substantially all of the amounts are carried with Nordea Bank of Finland PLC, DNB Bank ASA, Citibank, Standard Chartered and Danske Bank. However, we believe this risk is remote, as they are established and reputable establishments with no prior history of default. There is a concentration of financing risk with respect to our long-term debt to the extent that a substantial amount of our long-term debt is carried with K-Sure, KEXIM and commercial lenders of our $1.125 billion facility, as well as with ICBCL, CMBL, CCBFL, COSCO and CSSC in regards to our sale and leaseback arrangements (see note 5). We believe these counterparties to be sound financial institutions. Therefore, we believe this risk is remote. We have a substantial equity investment in our former subsidiary, Golar Partners, that from December 13, 2012 is considered as our affiliate and not our controlled subsidiary. As of December 31, 2018 , our ownership interest was 32.0% and the aggregate carrying value of the investments recorded in our balance sheet as of December 31, 2018 was $271.2 million , being the total of our ownership interest (common and general partner interests) plus IDRs. Accordingly, the value of our investments and the income generated from Golar Partners is subject to specific risks associated with its business. Golar Partners operates in the same business as us and as of December 31, 2018 had a fleet of ten vessels managed by us, under contract, with five of these vessels operating under medium to long-term charters. During the year ended December 31, 2018 , we recognized an impairment loss of $149.4 million on our investment in Golar Partners. Refer to note 9. We also have a substantial equity investment in our joint venture, Golar Power. As of December 31, 2018, our ownership interest was 50% and the aggregate carrying value of the investment recorded in our balance sheet as of December 31, 2018 was $266.2 million . Accordingly, the value of our investment and the income generated from Golar Power is subject to specific risks associated with its business. Golar Power offers integrated LNG based downstream solutions through the ownership and operation of FSRUs and associated terminal and power generation infrastructure. Furthermore, in the event the decline in the fair value of this investment falls below the carrying value and it was determined to be other-than-temporary, we would be required to recognize an impairment loss. A further concentration of supplier risk exists in relation to our vessels undergoing or pending FLNG conversion with Keppel and B&V. However, we believe this risk is remote as Keppel are global leaders in the shipbuilding and vessel conversion sectors while B&V is a global engineering, procurement and construction company.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	28. RELATED PARTY TRANSACTIONS a) Transactions with Golar Partners and subsidiaries: Income (expenses): (in thousands of $) 2018 2017 2016 Management and administrative services revenue (i) 9,809 7,762 4,251 Ship management fees revenue (ii) 5,200 5,903 6,466 Charterhire expenses (iii) — (17,423 ) (28,368 ) Interest expense on short-term credit facility (iv) — — (122 ) Share options expense recharge (vi) — 228 181 Interest expense on deposits payable (vii) (4,779 ) (4,622 ) (1,967 ) Total 10,230 (8,152 ) (19,559 ) Receivables (payables): The balances with Golar Partners and subsidiaries as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances owed from/ (to) Golar Partners and subsidiaries (iv) 4,091 (4,144 ) Methane Princess lease security deposit movements (v) (2,835 ) (3,464 ) Deposit payable (vii) — (177,247 ) Total 1,256 (184,855 ) (i) Management and administrative services agreement - On March 30, 2011, Golar Partners entered into a management and administrative services agreement with Golar Management, a wholly-owned subsidiary of Golar, pursuant to which Golar Management will provide to Golar Partners certain management and administrative services. The services provided by Golar Management are charged at cost plus a management fee equal to 5% of Golar Management’s costs and expenses incurred in connection with providing these services. Golar Partners may terminate the agreement by providing 120 days written notice. (ii) Ship management fees - Golar and certain of its affiliates charge ship management fees to Golar Partners for the provision of technical and commercial management of Golar Partners' vessels. Each of Golar Partners’ vessels is subject to management agreements pursuant to which certain commercial and technical management services are provided by Golar Management. Golar Partners may terminate these agreements by providing 30 days written notice. (iii) Charterhire expenses - This consists of the charterhire expenses that we incurred for the charter back from Golar Partners of the Golar Grand in 2015, 2016 and 2017. On November 1, 2017, the Golar Grand guarantee concluded. In connection with the sale of the Golar Grand to Golar Partners in November 2012, we issued an option where, in the event that the charterer did not renew or extend its charter for the Golar Grand beyond February 2015, the Partnership had the option to require us to charter the vessel through to October 2017. In February 2015, the option was exercised. Accordingly, we recognized charterhire costs of $17.4 million and $28.4 million for the year ended December 31, 2017 and 2016, respectively, in relation to the Golar Grand. The above disclosure excludes the net effect of the non-cash credit of $5.1 million and $6.1 million for the year ended December 31, 2017 and 2016, respectively. This relates to the Golar Grand guarantee obligation, which includes recognition of a loss on remeasurement in 2017, less amortization of the guarantee obligation. The Golar Grand guarantee concluded on November 2017. (iv) Trading balances - Receivables and payables with Golar Partners and its subsidiaries are comprised primarily of unpaid management fees and expenses for management, advisory and administrative services and may include working capital adjustments in respect of disposals to the Partnership, as well as charterhire expenses. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Partners and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. They primarily relate to recharges for trading expenses paid on behalf of Golar Partners, including ship management and administrative service fees due to us. In January 2016, we received funding from Golar Partners in the amount of $30 million for a fixed period of 60 days. Golar Partners charged interest on this balance at a rate of LIBOR plus 5.0% . (v) Methane Princess lease security deposit movements - This represents net advances from Golar Partners since its IPO, which correspond with the net release of funds from the security deposits held relating to a lease for the Methane Princess . This is in connection with the Methane Princess tax lease indemnity provided to Golar Partners under the Omnibus Agreement. Accordingly, these amounts will be settled as part of the eventual termination of the Methane Princess lease. (vi) Share options expense - This relates to a recharge of share option expense to Golar Partners in relation to share options in Golar granted to certain of Golar Partners' directors, officers and employees. (vii) Interest expense on deposits payable Expense under Tundra Letter Agreement - In May 2016, we completed the Golar Tundra Sale and received a total cash consideration of $107.2 million . We agreed to pay Golar Partners a daily fee plus operating expenses for the right to use the Golar Tundra from the date the Golar Tundra Sale was closed, until the date that the vessel would commence operations under the Golar Tundra Time Charter. In return, Golar Partners agreed to remit to us any hire income received with respect to the Golar Tundra during that period. It was further agreed that, if for any reason the Golar Tundra Time Charter had not commenced by the 12 month anniversary of the closing of the Golar Tundra Sale, Golar Partners had the right to require that we repurchase the shares of Tundra Corp at a price equal to the purchase price. Accordingly, by virtue of the put option, we continued to consolidate the Golar Tundra for the periods whilst the put option remained in place, thus we have accounted for $ nil , $2.2 million and $2.0 million as interest expense for the year ended December 31, 2018, 2017 and 2016, respectively. Deferred purchase price - In May 2017, the Golar Tundra had not commenced her charter and, accordingly, Golar Partners elected to exercise the Tundra Put Right to require us to repurchase Tundra Corp at a price equal to the original purchase price. In connection with Golar Partners exercising the Tundra Put Right, we and Golar Partners entered into an agreement pursuant to which we agreed to purchase Tundra Corp from Golar Partners on the date of the closing of the Tundra Put Sale (the "Put Sale Closing Date") in return we will be required to pay an amount equal to $107.2 million (the "Deferred Purchase Price") plus an additional amount equal to 5% per annum of the Deferred Purchase Price (the "Additional Amount"). The Deferred Purchase Price and the Additional Amount shall be due and payable by us on the earlier of (a) the date of the closing of the Hilli Disposal (see below) and (b) March 31, 2018. We agreed to accept the Deferred Purchase Price and the Additional Amount in lieu of a cash receipt on the Put Sale Closing Date in return we have provided Golar Partners with an option (which Golar Partners have exercised) to purchase an interest in Hilli Corp. We have accounted for $2.9 million and $1.1 million as interest expense for the year ended December 31, 2018 , and 2017 , respectively, in relation to the Deferred Purchase Price. Deposit received from Golar Partners - On August 15, 2017, we entered into a purchase and sale agreement (the "Hilli Sale Agreement") with Golar Partners for the disposal (the "Hilli Disposal") from Golar and affiliates of Keppel and Black & Veatch of common units (the "Disposal Interests") in Golar Hilli LLC. On the closing date of the Hilli Disposal, Golar Hilli LLC will indirectly (via its wholly-owned subsidiary) be the disponent owner of the Hilli . The Disposal Interests represent the equivalent of 50% of the two liquefaction trains, out of a total of four, that are contracted to the Perenco and SNH under an eight -year LTA. The sale price for the Disposal Interests is $658 million less 50% of the net lease obligations under the financing facility for the Hilli (the "Hilli Facility"), on closing date, plus post-closing purchase price adjustments. Concurrently with the execution of the Hilli Sale Agreement, we received a further $70 million deposit from Golar Partners, upon which we pay interest at a rate of 5% per annum. We have accounted for $1.9 million and $1.3 million as interest expense for the year ended December 31, 2018 , and 2017 , respectively, in relation to the $70 million deposit from Golar Partners. On July 12, 2018, we concluded the Hilli Disposal with Golar Partners, accordingly we applied the Deferred Purchase Price as well as the deposit received from Golar Partners against the disposal. Other transactions: Golar Partners distributions to us - Golar Partners has declared and paid quarterly distributions totaling $48.4 million , $52.3 million , and $54.7 million to us for each of the years ended December 31, 2018 , 2017 and 2016 , respectively. During the year ended December 31, 2018 , Hilli LLC had declared quarterly distributions totaling $5.6 million in respect of the Hilli Common Units owned by Golar Partners. As of December 31, 2018, we have a dividend payable of $3.6 million to Golar Partners. Exchange of Incentive Distribution Rights - Pursuant to the terms of an Exchange Agreement (the “Exchange Agreement”) by and between Golar and Golar Partners we exchanged all of our incentive distribution rights in the Partnership (“Old IDRs”) in October 2016. Under the terms of an Exchange Agreement, the first target distribution was met in November 2017, accordingly, Golar Partners issued 50% of the Earn-Out Units ( 374,295 common units and 7,639 general partner units) under the Exchange Agreement (see note 16). Indemnifications and guarantees: a) Tax lease indemnifications: Under the Omnibus Agreement, we have agreed to indemnify Golar Partners in the event of any tax liabilities in excess of scheduled or final settlement amounts arising from the Methane Princess leasing arrangement and the termination thereof. In addition, to the extent Golar Partners incurs any liabilities as a consequence of a successful challenge by the UK Tax Authorities with regard to the initial tax basis of the transactions relating to any of the UK tax leases or in relation to the lease restructuring terminations in 2010, we have agreed to indemnify Golar Partners. The maximum possible amount in respect of the tax lease indemnification is not known as the determination of this amount is dependent on our intention of terminating this lease and the various market factors present at the point of termination. As of December 31, 2018 , we recognized a liability of $11.5 million (2017: $11.5 million ) in respect of the tax lease indemnification to Golar Partners representing the fair value at deconsolidation in December 2012. b) Performance guarantees: We issued performance guarantees to third party charterers in connection with the Time Charter Party agreements entered into with the vessel operating entities who are now subsidiaries of Golar Partners. These performance guarantees relate to the Golar Freeze , the Methane Princess and the Golar Winter . The maximum potential exposure in respect of the performance guarantees issued by the Company is not known as these matters cannot be absolutely determined. The likelihood of triggering the performance guarantees is remote based on the past performance of both our and Golar Partners' combined fleets. c) Disposal of Golar Eskimo and Golar Igloo: Under the Purchase, Sale and Contribution Agreements entered into between Golar Partners and us on December 15, 2014 and December 5, 2013 in relation to the Golar Eskimo and the Golar Igloo, respectively, Golar has agreed to indemnify Golar Partners against certain environmental and toxic tort liabilities with respect to the assets that Golar contributed or sold to Golar Partners to the extent arising prior to the time they were sold and to the extent that Golar Partners notify us within five years of the date of the agreements. d) Golar Tundra financing related guarantees: In November 2015, we sold the Golar Tundra to a subsidiary of CMBL (see note 5) and subsequently leased back the vessel under a bareboat charter (the “Tundra Lease”). In connection with the Tundra Lease, we are a party to a guarantee in favor of Tundra SPV, pursuant to which, in the event that Tundra Corp (our subsidiary) is in default of its obligations under the Tundra Lease, we, as the primary guarantor, will settle any liabilities due within five business days. In addition, Golar Partners has also provided a further guarantee, pursuant to which, in the event we are unable to satisfy our obligations as the primary guarantor, Tundra SPV may recover this from Golar Partners, as the deficiency guarantor. Under a separate side agreement, we have agreed to indemnify Golar Partners for any costs incurred in its capacity as the deficiency guarantor. e) Hilli cost indemnification: We (as one of the Sellers) have agreed to indemnify Golar Partners for certain costs incurred in Hilli operations until August 14, 2025, when these costs exceed a contractual ceiling, capped at $20 million . Costs indemnified include vessel operating expenses, taxes, maintenance expenses, employee compensation and benefits, and capital expenditures. See note 6. Omnibus Agreement In connection with the IPO of Golar Partners, we entered into an Omnibus Agreement with Golar Partners governing, among other things, when we and Golar Partners may compete against each other as well as rights of first offer on certain FSRUs and LNG carriers. Under the Omnibus Agreement, Golar Partners and its subsidiaries agreed to grant a right of first offer on any proposed sale, transfer or other disposition of any vessel it may own. Likewise, we agreed to grant a similar right of first offer to Golar Partners for any vessel under a charter for five or more years that we may own. These rights of first offer will not apply to a (a) sale, transfer or other disposition of vessels between any affiliated subsidiaries, or pursuant to the terms of any current or future charter or other agreement with a charter party or (b) merger with or into, or sale of substantially all of the assets to, an unaffiliated third-party. In addition, the Omnibus Agreement provides for certain indemnities to Golar Partners in connection with the assets transferred from us. b) Transactions with Golar Power and affiliates: Net revenues: The transactions with Golar Power and its affiliates for the twelve months ended December 31, 2018 , 2017 and 2016 consisted of the following: (in thousands of $) 2018 2017 2016 Management and administrative services revenue 6,167 5,711 1,965 Ship management fees income 1,400 824 335 Debt guarantee compensation (i) 861 775 488 Other (247 ) 135 — Total 8,181 7,445 2,788 Payables: The balances with Golar Power and its affiliates as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances due to Golar Power and affiliates (ii) (5,417 ) (935 ) Total (5,417 ) (935 ) (i) Debt guarantee compensation - In connection with the closing of the Golar Power and Stonepeak transaction, Golar Power entered into agreements to compensate Golar in relation to certain debt guarantees (as further described under the subheading "Guarantees and other") relating to Golar Power and subsidiaries. This compensation amounted to an aggregate of $0.9 million and $0.8 million income for the year ended December 31, 2018 and 2017 , respectively. (ii) Trading balances - Receivables and payables with Golar Power and its subsidiaries are comprised primarily of unpaid management fees, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Power and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. Guarantees and other: a) Debt guarantees - The debt guarantees on the Golar Penguin and the Golar Celsius were previously issued by Golar to third party banks in respect of certain secured debt facilities relating to Golar Power and subsidiaries. As described in (i) above we receive compensation from Golar Power in relation to the provision of the guarantees. In addition, a debt guarantee was provided on the newbuild Golar Nanook. The liability which is recorded in "Other non-current liabilities" is being amortized over the remaining term of the respective debt facilities with the credit being recognized in "Other financial items". As of December 31, 2018 and 2017 , the Company guaranteed $393.5 million and $182.3 million , respectively of Golar Power's gross long-term debt obligations. The debt facilities are secured against specific vessels. b) Shipyard guarantee - In connection with the newbuilding contract for the construction of a FSRU, we provided a guarantee to cover the remaining milestone payments due to the shipyard. Pursuant to the formation of Golar Power and closing of the Stonepeak transaction, Golar Power's subsidiary, entered into a counter guarantee with us to indemnify us in the event we are required to pay out any monies due under the shipyard guarantee. The shipyard guarantee expired on September 27, 2018 as a result of final milestone payments made by Golar Power to the yard. c) Transactions with OneLNG and subsidiaries: Net revenues: The transactions with OneLNG and its subsidiaries for the year ended December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 2016 Management and administrative services revenue 1,399 6,463 586 Receivables: The balances with OneLNG and its subsidiaries as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances due from OneLNG (i) 8,169 7,898 (i) Trading balances - Receivables and payables with One LNG and its subsidiaries are comprised primarily of unpaid management fees, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from OneLNG are unsecured, interest-free and intended to be settled in the ordinary course of business. Subsequent to the decision to dissolve OneLNG, we have written off $12.7 million of the trading balance with OneLNG to 'Other operating income' in our Consolidated statements of income as we deem it to be no longer recoverable. The trade receivables of $ 8.2 million is net of this provision. In addition to the OneLNG trading balance write-off recognized in 'Other operating income', we had an additional write-off of $1.3 million of capitalised conversion costs in relation to the Gandria . d) Transaction with other related parties: Net revenues (expenses): The transactions with other related parties for the years ended December 31, 2018 , 2017 and 2016 consisted of the following: (in thousands of $) 2018 2017 2016 The Cool Pool (i) 151,152 59,838 32,254 Magni Partners (ii) (375 ) (260 ) (4,282 ) Total 150,777 59,578 27,972 Receivables (Payables): The balances with other related parties as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 The Cool Pool (i) 43,985 14,004 Magni Partners (ii) (8 ) 6 Total 43,977 14,010 (i) The Cool Pool - For the year ended December 31, 2018 we recognized net income of $151.2 million from our participation in the Cool Pool. Trade accounts receivable includes amounts due from the Cool Pool, amounting to $44.0 million as of December 31, 2018 (December 31, 2017 : $14.0 million ). The table below summarizes our net earnings (impacting each line item in our consolidated statement of operations) generated from our participation in the Cool Pool: (in thousands of $) 2018 2017 2016 Time and voyage charter revenues 177,139 77,975 37,345 Time charter revenues - collaborative arrangement 73,931 28,327 13,730 Voyage, charterhire expenses and commission expenses (16,717 ) (7,683 ) (7,681 ) Voyage, charterhire and commission expenses - collaborative arrangement (83,201 ) (38,781 ) (11,140 ) Net income from the Cool Pool 151,152 59,838 32,254 (ii) Magni Partners - Tor Olav Trøim is the founder of, and partner in, Magni Partners Limited, a privately held UK company, and is the ultimate beneficial owner of the company. Pursuant to an agreement between Magni Partners Limited and a Golar subsidiary, for the year ended December 31, 2018 and 2017, Golar was recharged $0.4 million and $0.3 million , respectively, for services provided on behalf of our affiliates. In December 31, 2016, Golar was recharged $3.9 million (this includes $3.0 million in relation to the transaction with Golar Power, which has been recorded as part of the loss on disposal of Golar Power in the income statement) for advisory services from a partner and director of Magni Partners Limited, other than Mr Trøim. In addition, for the year ended December 31, 2018 and 2017 Golar was recharged $0.04 million and $0.3 million , respectively, for travel relating to certain board members. Furthermore, for the year ended December 31, 2017 Golar was recharged $0.3 million for other travel and out of pocket expenses. All charges have been recharged to Golar at cost.

CAPITAL COMMITMENTS

CAPITAL COMMITMENTS	12 Months Ended
	Dec. 31, 2018
CAPITAL COMMITMENTS [Abstract]
CAPITAL COMMITMENTS	29. CAPITAL COMMITMENTS Conversions We have contracts with Keppel and Black & Veatch for the conversion of our LNG carrier, the Gimi into a FLNG, and we have agreed contract terms for the conversion of the Gandria to a FLNG. The Gimi has recently entered the Keppel shipyard to commence its conversion to a FLNG, whilst the Gandria is currently in lay-up awaiting delivery to Keppel for conversion. The conversion agreements for the Gimi and the Gandria are both subject to certain payments and lodging of a full Notice to Proceed. As at December 31, 2018 , the estimated timing of the outstanding payments in connection with the Limited Notice to Proceed on the Gimi conversion are as follows: (in thousands of $) Payable within 12 months to December 31, 2019 21,530 21,530 In February 2019, we entered into a 20 years Lease and Operate Agreement with BP for the charter of a FLNG unit, Gimi , to service the Greater Tortue Ahmeyim project, subject to certain conditions precedent. The estimated conversion cost of the Gimi is approximately $1.3 billion . As we have not lodged our final Notice to Proceed on the Gandria conversion contract, we have excluded the Gandria capital commitments in the above table. In addition we have excluded any capital commitments in relation to the conversion of the Viking into a FSRU as commencement of this project is subject to certain conditions precedent.

OTHER COMMITMENTS AND CONTINGEN

OTHER COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
OTHER COMMITMENTS AND CONTINGENCIES	30. OTHER COMMITMENTS AND CONTINGENCIES Assets pledged (in thousands of $) 2018 2017 Book value of vessels secured against long-term loans 3,244,291 2,032,747 As at December 31, 2018 and 2017 , Golar Partners common units of 21,226,586 and 20,852,291 , respectively, were pledged as security for the obligations under the Margin Loan Facility (see note 20). Other contractual commitments and contingencies UK tax lease benefits During 2003 we entered into six UK tax leases. Under the terms of the leasing arrangements, the benefits are derived primarily from the tax depreciation assumed to be available to the lessors as a result of their investment in the vessels. As is typical in these leasing arrangements, as the lessee we are obligated to maintain the lessor’s after-tax margin. Accordingly, in the event of any adverse tax changes or a successful challenge by the UK Tax Authorities (''HMRC'') with regard to the initial tax basis of the transactions, or in relation to the 2010 lease restructurings, or in the event of an early termination of the Methane Princess lease, we may be required to make additional payments principally to the UK vessel lessor, which could adversely affect our earnings or financial position. We would be required to return all, or a portion of, or in certain circumstances significantly more than, the upfront cash benefits that we received in respect of our lease financing transactions, including the 2010 restructurings and subsequent termination transactions. The gross cash benefit we received upfront on these leases amounted to approximately £41 million British Pounds (before deduction of fees). Of these six leases, we have since terminated five , with one lease remaining, being that of the Methane Princess lease. Pursuant to the deconsolidation of Golar Partners in 2012, Golar Partners is no longer considered a controlled entity but an affiliate and therefore as at December 31, 2018 , the capital lease obligation relating to this remaining UK tax lease is not included on our consolidated balance sheet. However, under the indemnity provisions of the Omnibus Agreement or the respective share purchase agreements, we have agreed to indemnify Golar Partners in the event of any tax liabilities in excess of scheduled or final scheduled amounts arising from the Methane Princess leasing arrangements and termination thereof. HMRC has been challenging the use of similar lease structures and has been engaged in litigation of a test case for some years. In August 2015, following an appeal to the Court of Appeal by the HMRC which set aside previous judgments in favor of the tax payer, the First Tier Tribunal (UK court) ruled in favor of HMRC. The tax payer in this particular ruling has the election to appeal the courts’ decision, but no appeal has been filed. The judgments of the First Tier Tribunal do not create binding precedent for other UK court decisions and therefore the ruling in favor of HMRC is not binding in the context of our structures. Further, we consider there are differences in the fact pattern and structure between this case and our 2003 leasing arrangements and therefore is not necessarily indicative of any outcome should HMRC challenge us, and we remain confident that our fact pattern is sufficiently different to succeed if we are challenged by HMRC. HMRC have written to our lessor to indicate that they believe our lease may be similar to the case noted above. We have reviewed the details of the case and the basis of the judgment with our legal and tax advisers to ascertain what impact, if any, the judgment may have on us and the possible range of exposure has been estimated at approximately £ nil to £115 million British Pounds. We are currently in conversation with HMRC on this matter and, as well as continuing to present the factual background of Golar's position, we are progressing the possibility of bringing this inquiry to a mutually satisfactory conclusion. Given the complexity of these discussions, it is impossible to quantify the reasonably possible loss, however we continue to estimate the possible range of exposures as set out above. Legal proceedings and claims We may, from time to time, be involved in legal proceedings and claims that arise in the ordinary course of business. A provision will be recognized in the financial statements only where we believe that a liability will be probable and for which the amounts are reasonably estimable, based upon the facts known prior to the issuance of the financial statements. Other In December 2005, we signed a shareholders' agreement in connection with the setting up of a jointly owned company to be named Egyptian Company for Gas Services S.A.E ("ECGS"), which was to be established to develop hydrocarbon business and in particular LNG related business in Egypt. As at December 31, 2018 , we had a commitment to pay $1.0 million to a third party, contingent upon the conclusion of a material commercial business transaction by ECGS as consideration for work performed in connection with the setting up and incorporation of ECGS. We are party to a shareholders’ agreement with a consortium of investors to fund the development of pipeline infrastructure and a FSRU which are intended to supply two power plants in the Ivory Coast. The project is currently in the initial design phase, with FID currently expected to be taken in the first half of 2019. Negotiations are underway with third party lenders for the financing of construction costs in the event a positive investment decision is made. During the initial phase of the project, our remaining contractual commitments for this project are estimated to be in the region of €0.5 million . In the event a positive FID is taken on the project, this could increase up to approximately €15 million . This figure is dependent upon a variety of factors such as whether third party financing is obtained for a portion of the construction costs. The timing of this range of payments is dependent on whether and when FID is made, progress of negotiations with lenders for non-investor financing, and the progress of eventual construction work. The nature of payments to the project could be made in a combination of capital contributions or interest-bearing shareholder loans. In 2017, we commenced arbitration proceedings arising from the delays and the termination of the Golar Tundra time charter with a former charterer. These proceedings are expected to conclude shortly. For the year ended December 31, 2018, we recovered $50.7 million in charter earnings, recognized in 'Other operating income' in the consolidated statements of operations. In relation to our investment in small-scale LNG services provider Avenir (see note 16), we are party to a combined commitment of up to $182.0 million from initial Avenir shareholders Stolt-Nielsen, Höegh and us. In November 2018, Avenir was capitalised with the placement of 110,000,000 new shares at a par price of US $1.00 per share. Following the initial equity offering, the founding partners are committed to fund $72.0 million of which Golar is committed to approximately $18 million .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2018
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	31. SUBSEQUENT EVENTS In January 2019, we entered into binding agreements with a Croatian project developer, LNG Hrvatska d.o.o., to convert the 2005 built Golar Viking into a FSRU, sell the converted vessel, and then operate and maintain the FSRU for a minimum of 10 years. Commencement of this project is subject to certain conditions precedent, including confirmation of project funding and receipt of a notice to proceed from LNG Hrvatska d.o.o. In February 2019, we declared a dividend of $ 0.15 per share in respect of the quarter ended December 31, 2018 and paid this in April 2019. In addition, Golar Partners made a final cash distribution of $ 0.40 per unit in February 2019 in respect of the quarter ended December 31, 2018, of which we received $ 9.2 million of dividend income in relation to our common and general partner units held at the record date. In February 2019, we entered into a 20 year Lease and Operate Agreement with BP Mauritania Investments Ltd (“BP”) for the charter of the FLNG unit, the Gimi , to service the Greater Tortue Ahmeyim project. The Gimi ’s conversion to a FLNG is expected to commence in April 2019 and the Gimi is expected to commence operations under the Lease and Operate Agreement in 2022. The estimated cost of the Gimi’s conversion is $ 1.3 billion , which we plan to fund through multiple financing facilities, including a $700 million long term financing facility that is currently in its final stages and that we plan to have available to us during construction. Once the Gimi is accepted under the contract, we anticipate annual contracted revenues less forecasted operating costs of approximately $215 million per year.

BASIS OF PREPARATION AND SIGN_2

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Basis of accounting and presentation	Basis of preparation These consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP"). The accounting policies set out below have been applied consistently to all periods in these consolidated financial statements, unless otherwise noted.
Principles of consolidation	Principles of consolidation A variable interest entity ("VIE") is defined by the accounting standard as a legal entity where either (a) equity interest holders as a group lack the characteristics of a controlling financial interest, including decision making ability and an interest in the entity's residual risks and rewards, or (b) the equity holders have not provided sufficient equity investment to permit the entity to finance its activities without additional subordinated financial support, or (c) the voting rights of some investors are not proportional to their obligations to absorb the expected losses of the entity, their rights to receive the expected residual returns of the entity, or both and substantially all of the entity's activities either involve or are conducted on behalf of an investor that has disproportionately few voting rights. A party that is a variable interest holder is required to consolidate a VIE if the holder has both (a) the power to direct the activities that most significantly impact the entity's economic performance and (b) the obligation to absorb losses that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The accompanying consolidated financial statements include the financial statements of the entities listed in notes 4 and 5. Investments in entities in which we directly or indirectly hold more than 50% of the voting control are consolidated in the financial statements, as well as certain variable interest entities in which the Company is deemed to be subject to a majority of the risk of loss from the VIE's activities or entitled to receive a majority of the entity's residual returns, or both. All inter-company balances and transactions are eliminated. The non-controlling interests of the above-mentioned subsidiaries were included in the consolidated balance sheets and statements of income as "Non-controlling interests". Changes in our ownership interest while we retain a controlling financial interest in a subsidiary are accounted for as equity transactions. The carrying amount of the non-controlling interest is adjusted to reflect our changed ownership interest, with any difference between the fair value of consideration and the amount of the adjusted non-controlling interest being recognized in equity. We recognize a gain or loss when a subsidiary issues its stock to third parties at a price per share in excess or below its carrying value resulting in a reduction in our ownership interest in the subsidiary. The gain or loss is recorded in the line "Additional paid-in capital". When a consolidated subsidiary issues preferred stock, they are classified as equity. Preferred stock issued by a consolidated subsidiary to non-controlling interests are recorded as non-controlling interests for the amount of the proceeds received upon issuance.
Foreign currencies	Foreign currencies Our functional currency is the U.S. dollar as the majority of the revenues are received in U.S. dollars and a majority of our expenditures are incurred in U.S. dollars. Our reporting currency is U.S. dollars. Transactions in foreign currencies during the year are translated into U.S. dollars at the exchange rates in effect at the date of the transaction. Monetary assets and liabilities are translated using exchange rates at the balance sheet date. Non-monetary assets and liabilities are translated using historical exchange rates. Foreign currency transaction and translation gains or losses are included in the consolidated balance sheets and consolidated statements of income.
Use of estimates	Use of estimates The preparation of financial statements in accordance with US GAAP requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. As of December 31, 2018 , we leased eight vessels from wholly-owned special purpose vehicles ("Lessor SPVs") of financial institutions in connection with our sale and leaseback transactions. While we do not hold any equity investments in these Lessor SPVs, we have determined that we are the primary beneficiary of these entities and, accordingly, we are required to consolidate these VIEs into our financial results. The key line items impacted by our consolidation of these VIEs are short-term and long-term debt, restricted cash and short-term deposits, non-controlling interests, interest income and interest expense. In consolidating these lessor VIEs, on a quarterly basis, we must make assumptions regarding (i) the debt amortization profile; (ii) the interest rate to be applied against the VIEs’ debt principal; and (iii) the VIE's application of cash receipts. Our estimates are therefore dependent upon the timeliness of receipt and accuracy of financial information provided by these lessor VIE entities. Upon receipt of the audited annual financial statements of the lessor VIEs, we will make a true-up adjustment for any material differences. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual or scrap value, charter rates, ship operating expenses, utilization and drydocking requirements. In relation to the oil derivative instrument (see note 27), the fair value was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the liquefaction tolling agreement ("LTA"). Significant inputs used in the valuation of the oil derivative instrument include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our oil derivative instrument is recognized in each period in current earnings in "Realized and unrealized gain on oil derivative instrument".
Fair value measurements	Fair value measurements We account for fair value measurement in accordance with the accounting standards guidance using fair value to measure assets and liabilities. The guidance provides a single definition of fair value, together with a framework for measuring it, and requires additional disclosure about the use of fair value to measure assets and liabilities.
Revenue and related expense recognition	Revenue and related expense recognition Time charter agreements Revenues include minimum lease payments under time charters, fees for positioning and repositioning vessels, and gross pool revenues. Revenues generated from time charters, which we generally classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Initial direct costs (those directly related to the negotiation and consummation of the lease) are deferred and allocated to earnings over the lease term. Rental income and expense are amortized over the lease term on a straight-line basis. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is offhire, for example when the vessel is undergoing repairs. These expenses are recognized as incurred. Vessel operating expenses, which are recognized when incurred, include crewing, repairs and maintenance, insurance, stores, lube oils, communication expenses and third party management fees. Bunkers consumption represents mainly bunkers consumed during unemployment and off-hire. Liquefaction services revenue Liquefaction services revenue is generated from a LTA entered into with our customer. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. The liquefaction services capacity provided to our customer is considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. Contractual payment terms for liquefaction services is monthly in arrears, after services have been provided, generally resulting in the recognition of contract assets. Contract assets are regularly assessed for impairment. Contract liabilities arise when the customer makes payments in advance of receiving services. The term between when invoicing and when payment is due is not significant. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Management fees Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. Commercial and technical vessel-related services include vessel maintenance, providing vessel crew, making arrangements for vessel insurance, bunkering, provisions and stores, invoicing and collecting vessel hire. Corporate and administrative services include corporate services, group accounting, treasury, legal, tax, consultancy and other administrative services. These services are provided to our customers Golar Partners and Golar Power. Our contracts generally have an initial contract term of one year or less, after which the arrangement continues with a short notice period to end the contract, ranging from 30 days to 180 days. Our management services provided are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. Contractual payment terms for management fees generally allow for billing and payment in advance of services being provided. However, contract liabilities did not arise because there was no billing in recognition for services rendered in future periods at the reporting date. Contract assets arise when we render management services in advance of receiving payment from our customers. Contract assets are regularly assessed for impairment. The transaction price is generally considered variable consideration given the key driver of consideration is actual costs incurred in a given period, which varies each period according to activity levels. The entire amount of the transaction price is allocated to the single performance obligation identified. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount we have the right to invoice. Cool Pool Pool revenues and expenses under the Cool Pool arrangement have been accounted for in accordance with the guidance for collaborative arrangements. In relation to our vessels participating within the pool, voyage expenses and commissions from collaborative arrangements include an allocation of our net results from the pool to the other participants. Each participants' share of the net pool revenues is based on the number of pool points attributable to its vessels and the number of days such vessels participated in the pool. We have presented our share of the net income earned under the Cool Pool arrangement across a number of line items in the income statement. For net revenues and expenses incurred relating specifically to Golar’s vessels, and for which we are deemed the principal, these will be presented gross on the face of the income statement in the line items "Time and voyage charter revenues" and "Voyage, charterhire and commission expenses". For pool net revenues generated by the other participants in the pooling arrangement, these will be presented separately in revenue and expenses from collaborative arrangements. Refer to note 28 for an analysis of the income statement effect for the pooling arrangement. Project development expenses With effect from the year ended December 31, 2018, we presented a new line item in operating expenses on the face of the statements of income. The new line item, "Project development expenses", includes the costs associated with pursuing future contracts and developing our pipeline of activities that have not met our internal threshold for capitalization. Previously, these costs were presented within "Administrative expenses" along with our general overhead costs. We believe that the introduction of this new line item in the statements of income provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods.
Cash and cash equivalents	Cash and cash equivalents We consider all demand and time deposits and highly liquid investments with original maturities of three months or less to be equivalent to cash.
Restricted cash and short-term deposits	Restricted cash and short-term deposits Restricted cash consists of bank deposits which may only be used to settle certain pre-arranged loans, bid bonds in respect of tenders for projects we have entered into, cash collateral required for certain swaps, and other claims which require us to restrict cash. Short-term deposits represent highly liquid deposits placed with financial institutions, primarily from our consolidated VIEs, which are readily convertible into known amounts of cash with original maturities of less than 12 months.
Trade accounts receivables	Trade accounts receivables Trade receivables are presented net of allowances for doubtful balances. At each balance sheet date, all potentially uncollectible accounts are assessed individually for purposes of determining the appropriate provision for doubtful accounts.
Inventories	Inventories Inventories, which are comprised principally of fuel, lubricating oils and vessel spares, are stated at the lower of cost and net realizable value. Cost is determined on a first-in, first-out basis.
Investments in affiliates	Investments in affiliates Affiliates are entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but over which we do not exercise control or have the power to control the financial and operational policies. Investments in these entities are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the participating rights of non-controlling interests. Under this method, we record our investment in the affiliate at cost (or fair value if a consequence of deconsolidation), and adjust the carrying amount for our share of the earnings or losses of the affiliate subsequent to the date of the investment and report the recognized earnings or losses in income. Dividends received from an affiliate reduce the carrying amount of the investment. The excess, if any, of the purchase price over book value of our investments in equity method affiliates, or basis difference, is included in the consolidated balance sheets as "Investments in affiliates". We allocate the basis difference across the assets and liabilities of the affiliate, with the residual assigned to goodwill. Any negative goodwill is recognized immediately in the income statement as a gain on bargain purchase. The basis difference will then be amortized through the consolidated statements of income as part of the equity method of accounting. When our share of losses in an affiliate equals or exceeds its interest, we do not recognize further losses, unless we have incurred obligations or made payments on behalf of the affiliate. We recognize gains and losses in earnings for the issuance of shares by our affiliates, provided that the issuance of such shares qualifies as a sale of such shares.
Cost method investments	Cost method investments Cost method investments are initially recorded at cost and reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Dividends received from cost method investments are recorded in the consolidated statements of income in the line item "Dividend income".
Vessels and equipment	Vessels and equipment Vessels and equipment are stated at cost less accumulated depreciation. The cost of vessels and equipment, less the estimated residual value, is depreciated on a straight-line basis over the assets' remaining useful economic lives. Management estimates the residual values of our vessels based on a scrap value cost of steel and aluminum times the weight of the ship noted in lightweight ton. Residual values are periodically reviewed and revised to recognize changes in conditions, new regulations or other reasons. The cost of building mooring equipment is capitalized and depreciated over the initial lease term of the related agreement. Refurbishment costs incurred during the period are capitalized as part of vessels and equipment and depreciated over the vessels' remaining useful economic lives. Refurbishment costs are costs that appreciably increase the capacity, or improve the efficiency or safety of vessels and equipment. Drydocking expenditures are capitalized when incurred and amortized over the period until the next anticipated drydocking, which is generally five years. For vessels that are newly built or acquired, we have adopted the "built-in overhaul" method of accounting. The built-in overhaul method is based on the segregation of vessel costs into those that should be depreciated over the useful life of the vessel and those that require drydocking at periodic intervals to reflect the different useful lives of the components of the assets. The estimated cost of the drydocking component is amortized until the date of the first drydocking following acquisition, upon which the cost is capitalized and the process is repeated. When a vessel is disposed, any unamortized drydocking expenditure is charged against income in the period of disposal. Vessel reactivation costs incurred on vessels leaving lay-up include both costs of a capital and expense nature. The capital costs include the addition of new equipment or modifications to the vessel which enhance or increase the operational efficiency and functionality of the vessel. These expenditures are capitalized and depreciated over the remaining useful life of the vessel. Expenditures of a routine repairs and maintenance nature that do not improve the operating efficiency or extend the useful lives of the vessels are expensed as incurred as mobilization costs. Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRUs and FLNG) 40 years Vessels - converted FSRUs 20 years from conversion date Vessels - FLNG 30 years from conversion date Drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years
Asset under development	Asset under development An asset is classified as asset under development when there is a firm commitment from us to proceed with the construction of the asset and the likelihood of conversion is virtually certain to occur. An asset under development is classified as non-current and is stated at cost. All costs incurred during the construction of the asset, including conversion installment payments, interest, supervision and technical costs are capitalized. Interest costs directly attributable to construction of the asset is added to the cost of the asset. Capitalization ceases, and depreciation commences, once the asset is completed and available for its intended use.
Interest costs capitalized	Interest costs capitalized Interest is capitalized on all qualifying assets that require a period of time to get them ready for their intended use. Qualifying assets consist of vessels under construction, assets under development and vessels undergoing conversion into FSRUs or FLNGs for our own use. In addition, certain equity method investments may be considered qualifying assets prior to commencement of their planned principal operation. The interest capitalized is calculated using the rate of interest on the loan to fund the expenditure or our weighted average cost of borrowings, where appropriate, from commencement of the asset development until substantially all the activities necessary to prepare the assets for its intended use are complete. If our financing plans associate a specific borrowing with a qualifying asset, we use the rate on that borrowing as the capitali z ation rate to be applied to that portion of the average accumulated expenditures for the asset provided that does not exceed the amount of that borrowing. We do not capitali z e amounts beyond the actual interest expense incurred in the period.
Asset retirement obligation	Asset retirement obligation An asset retirement obligation, or ARO, is a liability associated with the eventual retirement of a fixed asset. The fair value of an ARO is recorded as a liability in the period when the obligation arises. The fair value of the ARO is measured using expected future discounted cash outflows. When the liability is recognized, we also capitalize the related ARO cost by adding it to the carrying amount of the related fixed asset. Each period, the liability is increased for the change in its present value. Changes in the amount or timing of the estimated ARO are recorded as an adjustment to the related liability and asset.
Held-for-sale assets and disposal group	Held-for-sale assets and disposal group Individual assets or subsidiaries to be disposed of, by sale or otherwise in a single transaction, are classified as held-for-sale if all of the following criteria are met at the period end: • Management, having the authority to approve the action, commits to a plan to sell the assets or subsidiaries; • The asset or subsidiaries are available for immediate sale in its present condition subject only to terms that are usual and customary for such sales; • An active program to locate a buyer and other actions required to complete the plan to sell have been initiated; • The sale is probable; and • The transfer is expected to qualify for recognition as a completed sale, within one year. The term probable refers to a future sale that is likely to occur, the asset or subsidiaries (disposal group) is being actively marketed for sale at a price that is reasonable in relation to its current fair value and actions required to complete the plan indicate that it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn. A disposal group is classified as discontinued operations if the following criteria are met: (1) a component of an entity or group of components that has been disposed of by sale, disposed of other than by sale or is classified as held-for-sale that represents a strategic shift that has or will have a major effect on our financial results or (2) an acquired business or non-profit activity (the entity to be sold) that is classified as held-for-sale on the date of the acquisition. Assets or subsidiaries held-for-sale are carried at the lower of their carrying amount and fair value less costs to sell. Interest and other expenses attributable to the liabilities of a disposal group classified as held-for-sale shall continue to be accrued. On classification as held-for-sale, the assets are no longer depreciated. If, at any time, the criteria for held-for-sale is no longer met, then the asset or disposal group will be reclassified to held and used. The asset or disposal group will be valued at the lower of the carrying amount before the asset or disposal group was classified as held-for-sale (as adjusted for any subsequent depreciation and amortization), and its fair value. Any adjustment to the value is shown in consolidated statements of income for the period in which the criterion for held-for-sale was not met.
Impairment of non-current assets	Impairment of long-lived assets We continually monitor events and changes in circumstances that could indicate carrying amounts of long-lived assets may not be recoverable. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows and estimates in respect of residual or scrap value. When such events or changes in circumstances are present, we assess the recoverability of long-lived assets by determining whether the carrying value of such assets will be recovered through undiscounted expected future cash flows. If the total of the future cash flows is less than the carrying amount of those assets, we recognize an impairment loss based on the excess of the carrying amount over the lower of the fair market value of the assets, less cost to sell, and the net present value ("NPV") of estimated future undiscounted cash flows from the employment of the asset ("value-in-use").
Other-than temporary impairment of investments	Other-than-temporary impairment of investments Where there are indicators that fair value is below carrying value of our investments, we will evaluate these for other-than-temporary impairment. Consideration will be given to (1) the length of time and the extent to which fair value is below carrying value, (2) the financial condition and near-term prospects of the investee, and (3) our intent and ability to hold the investment until any anticipated recovery. Where determined to be other-than-temporary impairment, we will recognize an impairment loss in the period in the line item "Equity in net (losses) earnings of affiliates" the consolidated statements of income.
Deferred charges	Deferred charges Costs associated with long-term financing, including debt arrangement fees, are deferred and amortized over the term of the relevant loan under the effective interest method. Amortization of debt issuance costs is included in interest expense. These costs are presented as a deduction from the corresponding liability, consistent with debt discounts.
Derivatives	Derivatives We use derivatives to reduce market risks associated with our operations. We use interest rate swaps for the management of interest rate risk exposure. The interest rate swaps effectively convert a portion of our debt from a floating to a fixed rate over the life of the transactions without an exchange of underlying principal. We seek to reduce our exposure to fluctuations in foreign exchange rates through the use of foreign currency forward contracts. From time to time, we enter into equity swaps. Under these facilities, we swap with our counterparty (usually a major bank) the risk of fluctuations in our share price and the benefit of any dividends, for a fixed payment of LIBOR plus margin. The counterparty may acquire shares in the Company to hedge its own position. All derivative instruments are initially recorded at fair value as either assets or liabilities in the accompanying consolidated balance sheets and subsequently remeasured to fair value, regardless of the purpose or intent for holding the derivative. Where the fair value of a derivative instrument is a net liability, the derivative instrument is classified in "Other current liabilities" and "Other non-current liabilities", as appropriate, in the consolidated balance sheets. Where the fair value of a derivative instrument is a net asset, the derivative instrument is classified in "Other current assets" and "Other non-current assets", as appropriate, in the consolidated balance sheets. The changes in fair value of derivative financial instruments (excluding the oil derivative instrument) are recognized each period in current earnings in "(Losses) gains on derivative instruments" in the consolidated statements of income. We do not apply hedge accounting. The fair value of the oil derivative instrument was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA. Significant inputs used in the valuation of the oil derivative instrument include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our oil derivative instrument is recognized in each period in current earnings in "Realized and unrealized gain on oil derivative instrument". Cash flows from economic hedges are classified in the same category as the items subject to the economic hedging relationship.
Convertible bonds	Convertible bonds We account for debt instruments with convertible features in accordance with the details and substance of the instruments at the time of their issuance. For convertible debt instruments issued at a substantial premium to equivalent instruments without conversion features, or those that may be settled in cash upon conversion, it is presumed that the premium or cash conversion option represents an equity component. Accordingly, we determine the carrying amounts of the liability and equity components of such convertible debt instruments by first determining the carrying amount of the liability component by measuring the fair value of a similar liability that does not have an equity component. The carrying amount of the equity component representing the embedded conversion option is then determined by deducting the fair value of the liability component from the total proceeds from the issue. The resulting equity component is recorded, with a corresponding offset to debt discount which is subsequently amortized to interest cost using the effective interest method over the period the debt is expected to be outstanding as an additional non-cash interest expense. Transaction costs associated with the instrument are allocated pro-rata between the debt and equity components. For conventional convertible bonds which do not have a cash conversion option or where no substantial premium is received on issuance, it may not be appropriate to separate the bond into the liability and equity components.
Provisions	Provisions In the ordinary course of business, we are subject to various claims, lawsuits and complaints. Management, in consultation with internal and external advisers, will provide for a contingent loss in the financial statements if the contingency had occurred at the date of the financial statements and the likelihood of loss was probable and the amount can be reasonably estimated. If we determine that the reasonable estimate of the loss is a range and there is no best estimate within the range, we will provide the lower amount within the range.
Pensions	Pensions Defined benefit pension costs, assets and liabilities requires adjustment of the significant actuarial assumptions annually to reflect current market and economic conditions. Our accounting policy states that full recognition of the funded status of defined benefit pension plans is to be included within our consolidated balance sheets. The pension benefit obligation is calculated by using a projected unit credit method. Defined contribution pension costs represent the contributions payable to the scheme in respect of the accounting period and are recorded in the consolidated statements of income.
Guarantees	Guarantees Guarantees issued by us, excluding those that are guaranteeing our own performance, are recognized at fair value at the time that the guarantees are issued, or upon the deconsolidation of a subsidiary, and reported in "Other non-current liabilities". A liability is an amount equal to the fair value of the obligation undertaken in issuing the guarantee is recognized. If it becomes probable that we will have to perform under a guarantee, we will recognize an additional liability if the amount of the loss can be reasonably estimated. The recognition of fair value is not required for certain guarantees such as the parent's guarantee of a subsidiary's debt to a third party. For those guarantees excluded from the above guidance requiring the fair value recognition provision of the liability, financial statement disclosures of such items are made.
Treasury shares	Treasury shares Treasury shares are recognized as a separate component of equity at cost. Upon subsequent disposal of treasury shares, any consideration is recognized directly in equity.
Stock-based compensation	Stock-based compensation We expense the fair value of stock options issued to employees and non-employees over the period the options vest. We amortize stock-based compensation for awards on a straight-line basis over the period during which the individuals are required to provide service in exchange for the reward - the requisite service (vesting) period. No compensation cost is recognized for stock options for which the individuals do not render the requisite service. The fair value of share options is estimated using the Black-Scholes option pricing model.
Earnings per share	Earnings per share Basic earnings per share ("EPS") is computed based on the income available to common stockholders and the weighted average number of shares outstanding for basic EPS. Treasury shares are not included in the calculation. Diluted EPS includes the effect of the assumed conversion of potentially dilutive instruments. Such potentially dilutive common shares are excluded when the effect would be to increase earnings per share or reduce a loss per share.
Leases as lessee	Leases as lessee Rentals under operating leases where we are the lessee are recognized as an operating expense evenly over the lease term. Contingent rentals are recognized as an operating expense when incurred. The useful life of any leasehold improvements is limited to the shorter of the lease term or economic life of the leased asset. Lease incentives, uneven payments and initial direct costs are recognized evenly over the lease term. Agreements which include renewal options are included in the lease term when considered reasonably assured.
Income taxes	Income taxes Income taxes are based on a separate return basis. The guidance on "Income Taxes" prescribes a recognition threshold and measurement attributes for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Deferred tax assets and liabilities are recognized principally for the expected tax consequences of temporary differences between the tax bases of assets and liabilities and their reported amounts. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Realization of the deferred income tax asset is dependent on generating sufficient taxable income in future years. Deferred tax assets and liabilities are measured at the tax rates that are expected to apply to the year when the asset is realized or the liability is settled, based on the tax rates and tax laws that have been enacted or substantively enacted at the balance sheet date. Income tax relating to items recognized directly in the statement of comprehensive income is recognized in the statement of changes in equity and not in the consolidated statements of income. Penalties and interest related to uncertain tax positions are recognized in “Income taxes” in the consolidated statements of income.
Related parties	Related parties Parties are related if one party has the ability, directly or indirectly, to control the other party or exercise significant influence over the other party in making financial and operating decisions. Parties are also related if they are subject to common control or significant influence.
Segment reporting	Segment reporting A segment is a distinguishable component of the business that is engaged in business activities from which we earn revenues and incur expenses whose operating results are regularly reviewed by the chief operating decision maker, and which are subject to risks and rewards that are different from those of other segments. We have identified three reportable industry segments: vessel operations, FLNG and Power.
Adoption of new accounting standards & Accounting pronouncements that have been issued but not yet adopted	Adoption of new accounting standards In May 2014, the Financial Accounting Standards Board (the “FASB”) issued ASC 606 and subsequent amendments (Topic 606). The standard provides a single, comprehensive revenue recognition model and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We adopted this guidance on January 1, 2018, under a modified retrospective approach - see note 8 for further details. The adoption of this guidance impacts presentation and disclosure of our management fee revenue only, there is no impact to recognition or measurement. In January 2016, the FASB issued ASU 2016-01 Financial Instruments-Overall (Subtopic 825-10) : Recognition and Measurement of Financial Assets and Financial Liabilities , which made targeted improvements to the recognition, measurement, presentation and disclosure of financial instruments. We adopted the amendments to this ASU on January 1, 2018 under a modified retrospective approach except for equity securities without a determinable fair value, for which a prospective approach is prescribed. The adoption of this ASU did not have a material impact on the consolidated financial statements. In August 2016, the FASB issued ASU 2016-15 Statement of Cash Flows (Topic 230) : Classification of Certain Cash Receipts and Cash Payments , which provides guidance on the disclosure and classification of certain items within the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows. Following the adoption of the amendments to ASC 230, we have made an accounting policy election to classify distributions received from equity method investees using the "cumulative earnings approach" and, as a result, certain of the dividends received have been retrospectively reclassified, where required, as cash inflows from investing activities. We reclassified $25.1 million and 29.0 million for the years ended December 31, 2017 and 2016, respectively. In November 2016, the FASB issued ASU 2016-18 Statement of Cash Flows (Topic 230): Restricted Cash , which requires that restricted cash be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts presented on the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows and related disclosures. The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the twelve months ended December 31, 2017 and 2016: (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted December 31, 2016 OPERATING ACTIVITIES Restricted cash and short-term deposits 47,834 (47,834 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 22,928 (22,928 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (74,608 ) 74,608 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash 118,955 3,846 122,801 Cash, cash equivalents and restricted cash at beginning of period 105,235 412,182 517,417 Cash, cash equivalents and restricted cash at end of period 224,190 416,028 640,218 December 31, 2017 OPERATING ACTIVITIES Restricted cash and short-term deposits 57,110 (57,110 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 11,239 (11,239 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (50,136 ) 50,136 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash (9,328 ) (18,213 ) (27,541 ) Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 214,862 397,815 612,677 In January 2017, the FASB issued ASU 2017-01 Business Combinations (Topic 805): Clarifying the Definition of a Business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. We adopted this ASU prospectively from January 1, 2018. As a result, this increases the likelihood that future vessel dropdowns may be considered the sale of an asset rather than a business. However, this will be dependent upon the facts and circumstances of each prospective transaction. There was no material impact on the adoption of this ASU on our consolidated financial statements and related disclosures. In February 2017, the FASB issued ASU 2017-05 Other Income - Gains and Losses from the Derecognition of Non-Financial Assets . This ASU clarifies the scope of guidance applicable to sales of non-financial assets and also provides guidance on partial sales of such assets. We adopted this ASU prospectively from January 1, 2018. We expect any gain or loss on sale from future dropdowns, accounted for as a disposal, will be recognized in full on the disposal date, however this will be dependent on the facts and circumstances of each prospective transaction. There was no material impact to our consolidated financial statements and related disclosures on adoption of this standard. Accounting pronouncements that have been issued but not adopted In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) and subsequent amendments. Topic 842 modifies the definition of a lease, requires periodic reassessment of the lease term and requires new disclosures. Lessors are required to classify leases as sales-type, direct financ i ng or operating, with classification affecting the pattern of income recognition and provides guidance for sale and leaseback transactions. Topic 842 requires a lessee to recognize leases on its balance sheet by recording a lease liability (representing the obligation to make future lease payments) and a right of use asset (representing the right to use the asset for the lease term). Leases for lessees will be classified as either financing or operating with classification affecting the pattern of expense recognition in the income statement. Topic 842 will become effective for us on January 1, 2019. We have applied the modified retrospective transition approach. We will elect all available practical expedients which among other things allow us to carry forward prior conclusions relating to lease identification, classification and lease term. Our election of the practical expedient providing transition relief will result in our prior periods not being restated and will continue to be represented in accordance with Topic 840. Our minimum commitments relating to our existing operating leases are outlined in note 13 to the consolidated financial statements. The most significant impact of Topic 842 relates to our accounting for our office leases which will be recorded as assets and liabilities on our Balance Sheet from adoption. We do not believe that Topic 842 will have a notable impact on our liquidity and our debt covenant compliance under our current arrangements. For contracts where we are the lessor, the practical expedients we have elected results in no change to our Balance Sheet on adoption. Our legacy leases will continue to be classified in accordance with Topic 840, while modifications and subsequent accounting will follow the accounting under Topic 842. Leases entered into on or after January 1, 2019 will be assessed under the requirements of Topic 842. New lessor presentation and disclosure requirements are introduced and will be applied to our new and existing lease agreements in our subsequent reporting. In June 2016, the FASB issued ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and subsequent amendment ASU 2018-19 Codification Improvements to Topic 326 ‘‘Financial Instruments-Credit Losses” , which requires recognition and measurement of expected credit losses for financial assets and off balance sheet credit exposures. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics covering primarily minor corrections, clarifications and codification improvements. We are evaluating the impact of these amendments on our consolidated financial statements and related disclosures, which is not expected to have material impact on our consolidated financial statements. In August 2018, the FASB issued ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement . These amendments change the disclosures for fair value measurements - removing or modifying certain existing disclosure requirements, and adding new disclosure requirements. The guidance is effective for us commencing January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In August 2018, the FASB issued ASU 2018-14 Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans . These amendments change the disclosures for defined benefit plans - removing or clarifying certain existing disclosure requirements, and adding new disclosure requirements. The guidance is effective on a retrospective basis for us on January 1, 2021 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In August 2018, the FASB issued ASU 2018-15 Intangibles-Goodwill and Other- Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract . These amendments change the definition of a hosting arrangement and requires the capitalization of certain implementation costs. The guidance is effective on either a retrospective or prospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In October 2018, the FASB issued ASU 2018-17 Consolidation (Topic 810) - Targeted Improvements to Related Party Guidance for Variable Interest Entities . This amendment clarifies guidance for considering whether indirect interests held through related parties under common control are considered variable interests, increasing consistency of guidance for common control arrangements. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures. In November 2018, the FASB issued ASU 2018-18 Collaborative Arrangements (Topic 808) - Clarifying the Interaction between Topic 808 and Topic 606 . This amendment clarifies the interaction between Topic 808 ‘Collaborative Arrangements’ and Topic 606 ‘Revenue from Contracts with Customers’. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of these amendments on our consolidated financial statement disclosures.

BASIS OF PREPARATION AND SIGN_3

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2018
Accounting Policies [Abstract]
Schedule of Price Risk Derivatives	The realized and unrealized gain on oil derivative instrument is as follows: (in thousands of $) Year Ended 2018 2017 Realized gain on oil derivative instrument 26,737 — Unrealized (loss) gain on oil derivative instrument (9,970 ) 15,100 16,767 15,100
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted December 31, 2016 Administrative expenses 45,960 (8,658 ) 37,302 Project development expenses — 8,658 8,658 December 31, 2017 Administrative expenses 50,334 (12,303 ) 38,031 Project development expenses — 12,303 12,303 The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the twelve months ended December 31, 2017 and 2016: (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted December 31, 2016 OPERATING ACTIVITIES Restricted cash and short-term deposits 47,834 (47,834 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 22,928 (22,928 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (74,608 ) 74,608 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash 118,955 3,846 122,801 Cash, cash equivalents and restricted cash at beginning of period 105,235 412,182 517,417 Cash, cash equivalents and restricted cash at end of period 224,190 416,028 640,218 December 31, 2017 OPERATING ACTIVITIES Restricted cash and short-term deposits 57,110 (57,110 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 11,239 (11,239 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (50,136 ) 50,136 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash (9,328 ) (18,213 ) (27,541 ) Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 214,862 397,815 612,677
Schedule of useful lives applied in depreciation	Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRUs and FLNG) 40 years Vessels - converted FSRUs 20 years from conversion date Vessels - FLNG 30 years from conversion date Drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years
Schedule of Error Corrections and Prior Period Adjustments	The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted December 31, 2016 Change in fair value of derivative instruments — (26,644 ) (26,644 ) Change in assets and liabilities: Other current and non-current assets 14,924 (309 ) 14,615 Other current and non-current liabilities (17,273 ) 26,953 9,680 December 31, 2017 Change in fair value of derivative instruments — (24,498 ) (24,498 ) Change in assets and liabilities: Other current and non-current assets (102,453 ) 21,556 (80,897 ) Change in fair value of oil derivative instrument — (15,100 ) (15,100 ) Other current and non-current liabilities 81,844 18,042 99,886 The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments decrease As adjusted December 31, 2016 Gains (losses) on derivative instruments — 16,491 16,491 Other financial items, net 8,691 (16,491 ) (7,800 ) December 31, 2017 Gains (losses) on derivative instruments — 20,696 20,696 Other financial items, net 20,627 (20,696 ) (69 )

RECENTLY ISSUED ACCOUNTING ST_2

RECENTLY ISSUED ACCOUNTING STANDARDS (Tables)	12 Months Ended
	Dec. 31, 2018
Accounting Changes and Error Corrections [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The change in presentation for the years ended December 31, 2017 and 2016 are as follows: (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted December 31, 2016 Administrative expenses 45,960 (8,658 ) 37,302 Project development expenses — 8,658 8,658 December 31, 2017 Administrative expenses 50,334 (12,303 ) 38,031 Project development expenses — 12,303 12,303 The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the twelve months ended December 31, 2017 and 2016: (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted December 31, 2016 OPERATING ACTIVITIES Restricted cash and short-term deposits 47,834 (47,834 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 22,928 (22,928 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (74,608 ) 74,608 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash 118,955 3,846 122,801 Cash, cash equivalents and restricted cash at beginning of period 105,235 412,182 517,417 Cash, cash equivalents and restricted cash at end of period 224,190 416,028 640,218 December 31, 2017 OPERATING ACTIVITIES Restricted cash and short-term deposits 57,110 (57,110 ) — INVESTING ACTIVITIES Restricted cash and short-term deposits 11,239 (11,239 ) — FINANCING ACTIVITIES Restricted cash and short-term deposits (50,136 ) 50,136 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net (decrease) increase in cash, cash equivalents and restricted cash (9,328 ) (18,213 ) (27,541 ) Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 214,862 397,815 612,677

SUBSIDIARIES (Tables)

SUBSIDIARIES (Tables)	12 Months Ended
	Dec. 31, 2018
SUBSIDIARIES [Abstract]
Listing of significant subsidiaries	The following table lists our significant subsidiaries and their purpose as at December 31, 2018 . Unless otherwise indicated, we own a 100% ownership interest in each of the following subsidiaries. Name Jurisdiction of Incorporation Purpose Golar LNG 2216 Corporation Marshall Islands Owns and operates Golar Arctic Golar Management Limited United Kingdom Management company Golar Management Malaysia SDN. BDH. Malaysia Vessel management company Golar Management Norway AS Norway Vessel management company Golar Management D.O.O Croatia Vessel management company Golar GP LLC – Limited Liability Company Marshall Islands Holding company Golar LNG Energy Limited Bermuda Holding company Golar Gimi Corporation Marshall Islands Owns Gimi Golar Hilli Corp. * Marshall Islands Owns Hilli Episeyo (" Hilli ") Golar Gandria N.V. Curaçao Owns and operates Golar Gandria Golar Hull M2021 Corporation Marshall Islands Leases Golar Seal** Golar Hull M2022 Corporation Marshall Islands Leases Golar Crystal** Golar Hull M2027 Corporation Marshall Islands Owns and operates Golar Bear Golar Hull M2047 Corporation Marshall Islands Leases Golar Snow** Golar Hull M2048 Corporation Marshall Islands Leases Golar Ice** Golar LNG NB10 Corporation Marshall Islands Leases Golar Glacier** Golar LNG NB11 Corporation Marshall Islands Leases Golar Kelvin** Golar LNG NB12 Corporation Marshall Islands Owns and operates Golar Frost Golar LNG NB13 Corporation Marshall Islands Leases Golar Tundra** GVS Corporation Marshall Islands Owns and operates Golar Viking Golar Shoreline LNG Limited Bermuda Holding company Golar Hilli LLC * Marshall Islands Holding company * In February 2018, Golar Hilli LLC was incorporated with Golar as sole member. In July 2018, shares in Golar Hilli Corp. (a 89% owned subsidiary of Golar Hilli LLC) were exchanged for Hilli Common Units, Series A Special Units and Series B Special Units. See note 6 for further details. ** The above table excludes mention of the lessor variable interest entities (''lessor VIEs'') that we have leased vessels from under finance leases. The lessor VIEs are wholly-owned, newly formed special purpose vehicles ("SPVs") of financial institutions. While we do not hold any equity investments in these SPVs, we have concluded that we are the primary beneficiary of these lessor VIEs and accordingly have consolidated these entities into our financial results. See note 5 for further details.

VARIABLE INTEREST ENTITIES ("_2

VARIABLE INTEREST ENTITIES ("VIE") (Tables)	12 Months Ended
	Dec. 31, 2018
VARIABLE INTEREST ENTITIES [Abstract]
Schedule of sale leaseback transactions	The following table gives a summary of the sale and leaseback arrangements, including repurchase options and obligations as of December 31, 2018 : Vessel Effective from Sales value (in $ millions) First repurchase option (in $ millions) Date of first repurchase option Repurchase obligation at end of lease term (in $ millions) End of lease term Golar Glacier October 2014 204.0 173.8 October 2019 135.1 October 2024 Golar Kelvin January 2015 204.0 173.8 January 2020 135.1 January 2025 Golar Snow January 2015 204.0 173.8 January 2020 135.1 January 2025 Golar Ice February 2015 204.0 173.8 February 2020 135.1 February 2025 Golar Tundra November 2015 254.6 168.7 November 2018 (1) 76.4 November 2025 Golar Seal March 2016 203.0 132.8 March 2021 87.4 March 2026 Golar Crystal March 2017 187.0 97.3 March 2020 50.6 March 2027 Hilli June 2018 1,200.0 633.2 June 2023 300.0 June 2028 (1) We did not exercise the first repurchase option relating to the Golar Tundra .
Summary of the bareboat charter rates per day based on Base LIBOR Interest Rate for the next five years	A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of December 31, 2018 , are shown below: (in thousands of $) 2019 2020 2021 2022 2023 2024+ Golar Glacier 17,100 17,147 17,100 17,100 17,100 12,884 Golar Kelvin 17,100 17,147 17,100 17,100 17,100 15,695 Golar Snow 17,100 17,147 17,100 17,100 17,100 15,695 Golar Ice 17,100 17,147 17,100 17,100 17,100 18,599 Golar Tundra (1)(2) 22,437 21,548 20,610 19,697 18,784 32,079 Golar Seal (2) 13,754 13,717 13,717 13,717 13,754 27,433 Golar Crystal (1) 12,441 12,335 12,175 12,050 11,907 37,601 Hilli (1) 128,418 123,526 118,800 114,075 109,463 412,055 (1) The payment obligations relating to the Golar Tundra , Golar Crystal and Hilli above include variable rental payments due under the lease based on an assumed LIBOR plus a margin. (2) The payment obligations relating to the Golar Tundra and the Golar Seal above have been prepared on the assumption that we are able to secure a replacement charter for these two vessels, to ensure continuation of these financing arrangements. Refer to note 1 for further details.
Schedule of assets and liabilities of lessor VIEs	The assets and liabilities of the lessor VIEs that most significantly impact our consolidated balance sheets as of December 31, 2018 and 2017 , are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli 2018 2017 Assets Total Total Restricted cash and short-term deposits (see note 14) 21,170 71,924 19,294 8 — 3,405 3,186 57,441 176,428 130,063 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 39,319 182,540 30,404 117,888 121,741 — 5,741 148,880 646,513 833,664 Long-term interest bearing debt - non-current portion (1) 114,093 — 123,267 — — 123,524 90,790 749,100 1,200,774 252,691 153,412 182,540 153,671 117,888 121,741 123,524 96,531 897,980 1,847,287 1,086,355 (1) Where applicable, these balances are net of deferred finance charges (see note 20). The assets and liabilities of Hilli LLC that most significantly impact our consolidated balance sheet as of December 31, 2018, are as follows: (in thousands of $) Hilli LLC (2) Assets Cash and short-term deposits 85,238 Restricted cash and short-term deposits 57,441 Vessels and equipment, net 1,301,279 Other non-current assets 91,431 1,535,389 Liabilities Current portion of long-term debt and short-term debt (1) 148,880 Long-term interest bearing debt - non-current portion (1) 749,100 897,980 (1) Where applicable, these balances are net of deferred finance charges. (2) As Hilli LLC is the primary beneficiary of the Hilli Lessor VIE (see above) the Hilli LLC balances include the Hilli Lessor VIE.

DISPOSAL OF LONG-LIVED ASSETS (

DISPOSAL OF LONG-LIVED ASSETS (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Changes In Ownership Of a Subsidiary	The Hilli Disposal resulted in the following changes to our ownership interest in our consolidated subsidiary Hilli LLC in our equity: (in thousands of $) December 31, 2018 Net loss attributable to stockholders of Golar LNG Limited (231,428 ) Transfer to the non-controlling interests: increase in Golar LNG Limited’s paid-in capital for sale of 1,096 Hilli Common Units in July 2018 304,468 Changes from net income attributable to stockholders of Golar LNG Limited and transfers to non-controlling interests 73,040
Deconsolidation of Equity Method Investments	The table below illustrates how the loss on loss of control has been calculated: (in thousands of $) As of July 6, 2016 Net proceeds (a) 113,000 Fair value of 50% retained investment in Golar Power (b) 116,000 Fair value of counter guarantees from Golar Power (c) 3,701 Total fair value of Golar Power 232,701 Less: Carrying value of Golar Power’s net assets (d) 236,713 Guarantees issued by Golar to Golar Power (e) 4,471 Loss on loss of control of Golar Power (8,483 ) (a) Net proceeds received for the disposal of 50% in Golar Power The table below shows the purchase consideration we received for the disposal of a 50% interest in the ordinary share capital in Golar Power that was acquired by Stonepeak: (in thousands of $) As of July 6, 2016 Consideration received from Stonepeak 116,000 Less: Fee paid in relation to the transaction (3,000 ) Net proceeds 113,000 (b) Fair value of the retained investment in Golar Power The fair value of our retained investment, being the 50% interest in the ordinary share capital in Golar Power has been recorded at $116 million . The fair value was determined with reference to the consideration of $116 million we received from Stonepeak pertaining to the 50% ordinary share capital interest they acquired. Thus given that this was negotiated between third parties, this is representative of fair value. (c) Fair value of counter guarantees from Golar Power A number of counter guarantees were entered into by Golar Power for the benefit of Golar LNG, specifically to reimburse Golar for the historic legacy debt guarantees discussed in (e) below. In aggregate, based on the agreed premiums the fair value of these counter guarantees were calculated as $3.7 million . (d) Carrying value of Golar Power's net assets The table below shows the underlying carrying value of Golar Power's net assets at the deconsolidation date: (in thousands of $) As at July 6, 2016 ASSETS Current Cash and cash equivalents 10,992 Restricted cash 15,463 Trade accounts receivable 1,474 Other receivables, prepaid expenses and accrued income 178 Short term amounts due from related parties 3,000 Inventory 952 Total current assets 32,059 Non-current Newbuildings 50,436 Vessels, net 387,261 Total assets 469,756 LIABILITIES AND STOCKHOLDERS' EQUITY Current Current portion of long-term debt 20,032 Trade accounts payable 969 Accrued expenses 21,357 Total current liabilities 42,358 Non-current Long-term debt 190,685 Total liabilities 233,043 Equity Stockholders’ equity 236,713 Total liabilities and stockholders' equity 469,756 (e) Guarantees issued by Golar to Golar Power The guarantees issued by us in respect of Golar Power and its subsidiaries were fair valued as of the deconsolidation date which amounted to a liability of $4.5 million . This comprises of the following items: (in thousands of $) As of July 6, 2016 Debt guarantees 3,283 Shipyard guarantee 1,188 Total guarantees 4,471

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2018
Segment Reporting [Abstract]
Segment reporting information	December 31, 2018 December 31, 2017 December 31, 2016 (3) (in thousands of $) Vessel Operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 302,979 127,625 — — 430,604 143,537 — — — 143,537 80,257 — — — 80,257 Depreciation and amortization (65,496 ) (28,193 ) — — (93,689 ) (76,522 ) — — — (76,522 ) (72,972 ) — — — (72,972 ) Other operating expenses (231,887 ) (44,031 ) — — (275,918 ) (163,207 ) (4,365 ) — — (167,572 ) (144,816 ) (3,576 ) — — (148,392 ) Other operating gains and losses 50,740 2,749 — — 53,489 — 15,100 — — 15,100 16 — — — 16 Operating income (loss) 56,336 58,150 — — 114,486 (96,192 ) 10,735 — — (85,457 ) (137,515 ) (3,576 ) — — (141,091 ) Inter segment operating income (loss) (2) 335 — — (335 ) — 4,568 — — (4,568 ) — 275 — — (275 ) — Segment operating (loss) income 56,671 58,150 — (335 ) 114,486 (91,624 ) 10,735 — (4,568 ) (85,457 ) (137,240 ) (3,576 ) — (275 ) (141,091 ) Equity in net (losses) earnings of affiliates (138,676 ) (2,047 ) (16,913 ) — (157,636 ) 1,503 (8,153 ) (18,798 ) — (25,448 ) 37,344 — 10,534 — 47,878 Balance sheet: Total assets 2,990,506 1,555,389 266,151 (5,451 ) 4,806,595 3,025,244 1,515,463 228,696 (5,116 ) 4,764,287 3,152,311 978,614 126,534 (548 ) 4,256,911 Investment in affiliates 305,631 — 266,151 — 571,782 472,482 2,047 228,696 — 703,225 512,046 10,200 126,534 — 648,780 Capital expenditures 22,978 116,715 — — 139,693 1,349 390,552 — — 391,901 33,698 200,820 — — 234,518 (1) Eliminations required for consolidation purposes. (2) Inter segment operating income (loss) relates to management fee and charterhire revenues between the segments. (3) We no longer consider LNG trading a separate reportable segment. Given the previously reported segment information was immaterial for all periods presented, we have included these amounts within the vessel operations segment.
Revenue by major customer	In the years ended December 31, 2018 , 2017 and 2016 , revenues from the following customers accounted for over 10% of our consolidated time and voyage charter revenues: (in thousands of $) 2018 2017 2016 The Cool Pool (1) 251,070 62 % 106,302 91 % 51,075 77 % Perenco and SNH (note 8) 127,625 31 % — — % — — % An energy and logistics company 9,235 2 % 9,235 8 % 7,975 12 % (1) The 2018 Cool Pool revenue of $251.1 million includes revenue of $73.9 million that is separately disclosed in the consolidated statements of operations as from a collaborative arrangement. The balance of $177.2 million was derived from Golar vessels operating within the Cool Pool, and is included within the caption "Time and voyage charter revenues" in the consolidated statements of operations. See note 28.
Revenue from External Customers by Geographic Areas	The following geographical data presents our revenues from customers and fixed assets with respect only to our FLNG, while operating under the LTA, in Cameroon. In time and voyage charters for LNG carriers (or our FSRU, operating as a LNG carrier), the charterer, not us, controls the routes of our vessels. These routes can be worldwide as determined by the charterers. Accordingly, our management, including the chief operating decision maker, do not evaluate our performance either according to customer or geographical region. (in thousands of $) 2018 2017 2016 Cameroon Liquefaction services revenue 127,625 — — Total assets 1,535,389 1,515,463 —

REVENUE (Tables)

REVENUE (Tables)	12 Months Ended
	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Change in Contract with Customer, Asset and Liability	Contract assets arise when we render services in advance of receiving payment from our customers. Contract liabilities arise when the customer makes payments in advance of receiving the services. Changes in our contract balances during the period are as follows: (in thousands of $) Contract assets (1) Contract liabilities (2) Opening balance on January 1, 2018 17,245 — Payments received for services billed (14,558 ) — Services provided and billed in current period 143,670 33,763 Payments received for services billed in current period (120,975 ) — Impairment (1,006 ) — Deferred commissioning period revenue — (2,467 ) Closing balance on December 31, 2018 24,376 31,296 (1) Relates to management fee revenue and liquefaction services revenue, see a) and b) below. (2) Relates to liquefaction services revenue, see b) below.
Disaggregation of Revenue	The Hilli is moored in close proximity to the Customer’s gasfields, providing liquefaction service capacity over the term of the LTA. Liquefaction services revenue recognized comprises the following amounts: Year Ended (in thousands of $) 2018 2017 Base tolling fee (1) 119,677 — Amortization of deferred commissioning period revenue (2) 2,467 — Amortization of Day 1 gain (3) 5,817 — Other (336 ) — Total 127,625 — (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel (included in "Liquefaction services revenue" in the consolidated statements of income), and at an increased rate when the oil price is greater than $60 per barrel (recognized as a derivative and included in "Realized and unrealized gain on oil derivative instrument" in the consolidated statements of income, excluded from revenue and from the transaction price). (2) Customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, of $33.8 million is considered an upfront payment for services. These amounts billed are deferred (included in "Other current liabilities" and "Other non-current liabilities" in the consolidated balance sheets) and recognized as part of "Liquefaction services revenue" in the consolidated statements of income evenly over the contract term. (3) The Day 1 gain was established when the oil derivative instrument was initially recognized in December 2017 for $79.6 million (recognized in "Other current liabilities" and "Other non-current liabilities" in the consolidated balance sheets). This amount is amortized and recognized as part of "Liquefaction services revenue" in the consolidated statements of income evenly over the contract term.

IMPAIRMENT OF NON-CURRENT ASS_2

IMPAIRMENT OF NON-CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2018
IMPAIRMENT OF LONG-TERM ASSETS [Abstract]
Impairment of non-current assets	The following table presents the impairment charge recognized in relation to equipment included in "Other non-current assets", acquired due to uncertainty of the future usage of this equipment: (in thousands of $) 2018 2017 2016 Impairment charge — — 1,706 The following table presents the market values and carrying values of nine of our vessels that we have determined to have market values that are less than their carrying values as of December 31, 2018 . However, based on the estimated future undiscounted cash flows of these vessels, which are significantly greater than the respective carrying values, no impairment was recognized. (in thousands of $) Vessel 2018 Market value (1) 2018 Carrying value Deficit Golar Arctic 76,750 134,400 57,650 Golar Seal 178,750 179,000 250 Golar Bear 182,000 183,900 1,900 Golar Frost 182,000 187,700 5,700 Golar Viking 78,250 112,300 34,050 Golar Glacier 182,500 183,500 1,000 Golar Snow 184,500 191,800 7,300 Golar Ice 184,000 192,000 8,000 Golar Kelvin 183,500 185,600 2,100 (1) Market values are determined using reference to average broker values provided by independent brokers. Broker values are considered an estimate of the market value for the purpose of determining whether an impairment trigger exists. Broker values are commonly used and accepted by our lenders in relation to determining compliance with relevant covenants in applicable credit facilities for the purpose of assessing security quality.

(LOSSES) GAINS ON DERIVATIVE _2

(LOSSES) GAINS ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET (Tables)	12 Months Ended
	Dec. 31, 2018
OTHER FINANCIAL ITEMS, NET [Abstract]
Derivative Instruments, Gain (Loss)	(Losses) gains on derivative instruments comprise of the following: (in thousands of $) 2018 2017 2016 Mark-to-market adjustment for interest rate swap derivatives (see note 27) 604 6,614 2,818 Mark-to-market adjustment for equity derivatives (see note 27) (30,663 ) 16,622 24,819 Mark-to-market adjustment for foreign exchange swap derivatives (1,151 ) 821 (993 ) Unrealized mark-to-market (losses) gains on Earn-Out Units (see note 19) (7,400 ) 441 — Interest income (expense) on undesignated interest rate swaps (see note 27) 8,069 (3,802 ) (10,153 ) (30,541 ) 20,696 16,491
Components of other financial items, net	Other financial items, net comprise of the following: (in thousands of $) 2018 2017 2016 Impairment of loan (1) — — (7,627 ) Financing arrangement fees and other costs (244 ) (677 ) (404 ) Amortization of debt guarantee 861 1,548 1,563 Foreign exchange loss on operations (1,997 ) (888 ) (1,909 ) Other (101 ) (52 ) 577 (1,481 ) (69 ) (7,800 ) (1) Given the announcement of a negative Final Investment Decision from the Douglas Channel Project consortium in 2014, we reassessed the recoverability of the loan and accrued interest receivables from the Douglas Channel LNG Assets Partnership ("DCLAP") and concluded that DCLAP would not have the means to satisfy its obligations under the loan. Accordingly, we recognized an impairment charge of $7.6 million in 2016.

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Components of income tax expense (benefit)	The components of income tax expense (benefit) are as follows: Year ended December 31 (in thousands of $) 2018 2017 2016 Current tax expense 836 1,478 1,035 Deferred tax expense 431 27 90 Amortization of tax benefit arising on intra-group transfers of non-current assets — — (1,714 ) Total income tax expense (benefit) 1,267 1,505 (589 )
Schedule of effective income tax rate reconciliation	The income taxes for the years ended December 31, 2018 , 2017 and 2016 differed from the amount computed by applying the Bermuda statutory income tax rate of 0% as follows: Year ended December 31 (in thousands of $) 2018 2017 2016 Income taxes at statutory rate — — — Effect of deferred tax benefit on intra-group transfers of non-current assets — — (1,714 ) Effect of movement in deferred tax balances 431 27 90 Effect of adjustments in respect of current tax in prior periods (369 ) (5 ) (334 ) Effect of taxable income in various countries 1,205 1,483 1,369 Total tax expense (benefit) 1,267 1,505 (589 )

LOSS PER SHARE (Tables)

LOSS PER SHARE (Tables)	12 Months Ended
	Dec. 31, 2018
Earnings Per Share [Abstract]
Components of earnings per share, basic and diluted	The components of the numerator for the calculation of basic and diluted EPS are as follows: (in thousands of $) 2018 2017 2016 Net loss attributable to Golar LNG Ltd stockholders - basic and diluted (231,428 ) (179,703 ) (186,531 ) The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) 2018 2017 2016 Basic and diluted loss per share: Weighted average number of common shares outstanding 100,684 100,597 93,933 Loss per share are as follows: 2018 2017 2016 Basic and diluted $ (2.30 ) $ (1.79 ) $ (1.99 )

OPERATING LEASES (Tables)

OPERATING LEASES (Tables)	12 Months Ended
	Dec. 31, 2018
Leases [Abstract]
Minimum contractual future revenues to be received on time charters	The minimum contractual future revenues to be received on time charters in respect of our vessels as of December 31, 2018 , were as follows: Year ending December 31 (in thousands of $) 2019 25,851 Total 25,851
Future minimum rental payments under non-cancellable operating leases	The future minimum rental payments under our non-cancellable operating leases are as follows: Year ending December 31 Total (in thousands of $) 2019 5,417 2020 3,756 2021 2,682 2022 2,425 2023 and thereafter 6,180 Total minimum lease payments 20,460

RESTRICTED CASH AND SHORT-TER_2

RESTRICTED CASH AND SHORT-TERM DEPOSITS (Tables)	12 Months Ended
	Dec. 31, 2018
Restricted Cash and Investments [Abstract]
Components of restricted cash and cash equivalents	Our restricted cash and short-term deposits balances are as follows: (in thousands of $) 2018 2017 Restricted cash relating to the total return equity swap (1) 82,863 58,351 Restricted cash in relation to the Hilli (2) 174,597 174,737 Restricted cash and short-term deposits held by lessor VIEs (3) 176,428 130,063 Restricted cash relating to the $1.125 billion debt facility (4) 17,657 33,752 Collateral on the Margin Loan Facility (5) 33,413 — Restricted cash relating to office lease 777 813 Bank guarantee 691 99 Total restricted cash and short-term deposits 486,426 397,815 Less: Amounts included in current restricted cash and short-term deposits (332,033 ) (222,265 ) Long-term restricted cash 154,393 175,550 (1) Restricted cash relating to the share repurchase forward swap refers to the collateral required by the bank with whom we entered into a total return equity swap. Collateral of 20% of the total purchase price is required and this is subsequently adjusted with reference to the Company's share price (see note 27). (2) In November 2015, in connection with the issuance of a $400 million letter of credit by a financial institution to our project partner involved in the Hilli FLNG project, we posted an initial cash collateral sum of $305.0 million to support the performance guarantee. Under the provisions of the $400 million letter of credit, the terms allow for a stepped reduction in the value of the guarantee over time and thus, conversely, a reduction in the cash collateral requirements. Effective December 19, 2017, the $400 million letter of credit reduced to $300 million . The corresponding release of $57.2 million cash collateral reduced the cash collateral requirement to $174.7 million at December 31, 2017, with no further reduction in 2018. It is expected that the letter of credit will further reduce to $250.0 million during 2019. In November 2016, after certain conditions precedent were satisfied by the Company, the letter of credit required in accordance with the signed LTA was re-issued and, with an initial expiry date of December 31, 2018, the letter of credit automatically extends, on an annual basis, until the tenth anniversary of the acceptance date of the Hilli by the charterer, unless the bank should exercise its option to exit from this arrangement by giving three months' notice prior to the annual renewal date. (3) These are amounts held by lessor VIE entities that we are required to consolidate under U.S. GAAP into our financial statements as VIEs (see note 5). (4) This refers to cash deposits required under the $1.125 billion debt facility (see note 20). The covenant requires that, on the second anniversary of drawdown under the facility, where we fall below a prescribed EBITDA to debt service ratio, additional cash deposits with the financial institution are required to be made or maintained. (5) Collateral held against the Margin Loan Facility is required to satisfy one of the mandatory prepayment events within the facility, with this having been triggered when the closing price of the Golar Partners common units pledged by us as security for the obligations under the facility fell below a defined threshold. If certain requirements are met, the facility allows for the release of the collateral (see note 20).

OTHER CURRENT ASSETS (Tables)

OTHER CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2018
Other Assets [Abstract]
Components of other receivables, prepaid expenses and accrued income	(in thousands of $) 2018 2017 Prepaid expenses 4,285 3,045 Other receivables 14,435 3,002 18,720 6,047

INVESTMENTS IN AFFILIATES (Tabl

INVESTMENTS IN AFFILIATES (Tables)	12 Months Ended
	Dec. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Participation percentages, carrying amounts and components of non-consolidated investees	At December 31, 2018 and 2017 , we have the following participation in investments that are recorded using the equity method: 2018 2017 Golar Partners (1) 32.0 % 31.8 % Egyptian Company for Gas Services S.A.E ("ECGS") 50 % 50 % Golar Power 50 % 50 % OneLNG 51 % 51 % The Cool Pool Limited ("Pool Manager") (2) 50 % 33 % Avenir LNG Limited ("Avenir") 22.5 % — (1) As of December 31, 2018 , we held a 32.0% ( 2017 : 31.8% ) ownership interest in Golar Partners (including our 2% general partner interest) and 100% of the IDRs. (2) The Pool Manager is a Marshall Islands service company that was established in September 2015 to facilitate the joint operations under the Cool Pool. Following the exit of one participant from the pool in June 2018, our participation increased to 50% . The carrying amounts of our investments in our equity method investments as at December 31, 2018 and 2017 are as follows: (in thousands of $) 2018 2017 Golar Partners 271,160 467,097 Golar Power 266,151 228,696 OneLNG — 2,047 Avenir 28,710 — Others (1) 5,761 5,385 Equity in net assets of affiliates 571,782 703,225 1 Others largely relate to our investment in ECGS amounting to $5.3 million and $5.4 million as at December 31, 2018 and 2017 , respectively. The components of equity in net assets of non-consolidated affiliates are as follows: (in thousands of $) 2018 2017 Cost 981,196 877,810 Dividends (336,286 ) (287,263 ) Equity in net earnings of affiliates 95,458 107,553 Impairment of investment in affiliate (149,389 ) — Share of other comprehensive income of affiliates (19,197 ) 5,125 Equity in net assets of affiliates 571,782 703,225
Summarized financial information of affiliated undertakings	Summarized financial information of the affiliated undertakings shown on a 100% basis are as follows: (in thousands of $) December 31, 2018 December 31, 2017 ECGS Golar Partners Pool Manager Golar Power OneLNG Avenir ECGS Golar Partners Pool Manager Golar Power OneLNG Balance Sheet Current assets 22,955 164,529 98,448 79,029 4,884 78,591 37,476 311,496 40,661 61,374 14,955 Non-current assets 244 2,076,288 — 955,100 — 20,840 333 2,115,875 — 713,646 — Current liabilities 11,510 323,508 98,448 285,447 8,741 1,760 25,836 180,087 40,661 60,033 10,941 Non-current liabilities 1,203 1,157,792 — 149,114 — — 1,203 1,399,683 — 174,656 — Non-controlling interests — 79,902 — 1,541 — — — 76,544 — — — Statement of Operations Revenue 30,596 346,650 346,170 78,732 7 487 44,052 433,102 159,460 7,354 — Net income (loss) 207 76,548 — (10,202 ) (6,646 ) (975 ) 1,047 144,848 — (7,899 ) (14,883 )

ASSET UNDER DEVELOPMENT (Tables

ASSET UNDER DEVELOPMENT (Tables)	12 Months Ended
	Dec. 31, 2018
Extractive Industries [Abstract]
Schedule of asset under development	(in thousands of $) 2018 2017 Purchase price installments — 962,709 Interest costs capitalized — 116,416 Other costs capitalized (1) 20,000 98,364 20,000 1,177,489 (1) Other capitalized costs relate to the carrying value of the vessel earmarked for conversion.

VESSELS AND EQUIPMENT, NET (Tab

VESSELS AND EQUIPMENT, NET (Tables)	12 Months Ended
	Dec. 31, 2018
Property and equipment:
Components of vessels and equipment, net	Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRUs and FLNG) 40 years Vessels - converted FSRUs 20 years from conversion date Vessels - FLNG 30 years from conversion date Drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years
Vessels and equipment
Property and equipment:
Components of vessels and equipment, net	(in thousands of $) 2018 2017 Cost As of January 1 2,431,136 2,438,720 Additions 11,304 1,349 Transfer from asset under development (1) 1,296,431 — Transfer to asset under development (90,828 ) — Write-offs (9,995 ) (8,933 ) As of December 31 3,638,048 2,431,136 Depreciation, amortization and impairment As of January 1 (354,077 ) (284,889 ) Charge for the year (2) (93,415 ) (76,522 ) Transfer to asset under development 70,828 — Write-offs 9,995 7,334 As of December 31 (366,669 ) (354,077 ) — Net book value as at December 31 3,271,379 2,077,059 (1) On completion of the Hilli FLNG conversion and commissioning, we reclassified the total balance from "Asset under development" in our consolidated balance sheet as of December 31, 2018 . Capitalized interest costs of $148.1 million are included in the cost amounts above as of December 31, 2018 . (2) Depreciation and amortization charge for the year ended December 31, 2018 excludes $0.3 million of amortization charged to non-current assets in relation to the Cameroon License fee.

OTHER NON-CURRENT ASSETS (Table

OTHER NON-CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2018
OTHER NON-CURRENT ASSETS [Abstract]
Components of other non-current assets	(in thousands of $) 2018 2017 Oil derivative instrument (see note 27) 84,730 94,700 Other non-current assets (1) 40,729 37,891 Mark-to-market interest rate swaps valuation (see note 27) 6,298 10,166 OLT Offshore LNG Toscana S.p.A ("OLT–O") (2) 7,347 7,347 Derivatives - other (see note 16) — 7,400 139,104 157,504 (1) "Other non-current assets" is mainly comprised of payments made relating to long lead items ordered in preparation for the conversion of the Gimi into a FLNG vessel. As of December 31, 2018 and 2017 , the aggregate carrying value was $31.0 million . The Gimi conversion contract was executed on December 13, 2018 subsequent to the receipt of a limited Notice to Proceed from BP in relation to the Greater Tortue Ahmeyim project. (2) "Investment in OLT Offshore LNG Toscana S.p.A ("OLT-O")" refers to our investment in an Italian incorporated unlisted company which is involved in the construction, development, operation and maintenance of a FSRU terminal to be situated off the Livorno coast of Italy. In prior years, this investment was classified as a cost method investment. Following the adoption of ASU 2016-01, we have applied the measurement alternative for measuring equity investments without readily determinable fair values. As of December 31, 2018 and 2017, our investment in OLT-O was $7.3 million , representing a 2.7% interest in OLT-O’s issued share capital.

DEBT (Tables)

DEBT (Tables)	12 Months Ended
	Dec. 31, 2018
Debt Disclosure [Abstract]
Components of long-term debt (including related parties)	(in thousands of $) 2018 2017 Total long-term and short-term debt 2,565,359 2,410,847 Less: current portion of long-term debt and short-term debt (730,257 ) (1,384,933 ) Long-term debt 1,835,102 1,025,914
Future repayments of outstanding debt (including related parties)	The outstanding debt as of December 31, 2018 is repayable as follows: Year ending December 31 Golar debt VIE debt (1) Total debt (in thousands of $) 2019 85,225 646,959 732,184 2020 163,383 82,260 245,643 2021 21,716 82,260 103,976 2022 375,377 82,260 457,637 2023 21,716 82,260 103,976 2024 and thereafter 65,151 873,629 938,780 Total 732,568 1,849,628 2,582,196 Deferred finance charges (14,494 ) (2,343 ) (16,837 ) Total 718,074 1,847,285 2,565,359 (1) These amounts relate to certain lessor entities (for which legal ownership resides with financial institutions) that we are required to consolidate under U.S. GAAP into our financial statements as variable interest entities (see note 5).
Components of debt	At December 31, 2018 and 2017 , our debt was as follows: (in thousands of $) 2018 2017 Maturity date Golar Arctic facility 58,300 65,600 2019 Golar Viking facility 46,875 52,083 2020 2017 Convertible bonds 353,661 340,173 2022 Margin Loan 100,000 119,125 2020 FLNG Hilli facility — 525,000 2018 Hilli shareholder loans: - Keppel loan — 44,066 2027 - B&V loan — 5,000 2027 $1.125 billion facility: - Golar Bear facility 86,200 96,975 2024/2026* - Golar Frost facility 87,532 98,474 2024/2026* Subtotal (excluding lessor VIE loans) 732,568 1,346,496 ICBCL VIE loans: - Golar Glacier facility 154,226 161,876 2018/2024** - Golar Snow facility 154,566 162,566 2018/2025** - Golar Kelvin facility 182,540 182,540 ** - Golar Ice facility 117,888 134,954 ** CMBL VIE loan: - Golar Tundra facility 121,741 198,613 2026** CCBFL VIE loan: - Golar Seal facility 123,524 143,849 2026** COSCO VIE loan: - Golar Crystal facility 97,163 104,006 2027** CSSC VIE loan: - Hilli facility 897,980 — 2028** Total debt (gross) 2,582,196 2,434,900 Deferred finance charges (16,837 ) (24,053 ) Total debt 2,565,359 2,410,847 * The commercial loan tranche matures earlier of the two dates, with the remaining balance maturing at the latter date. However, in the event that the commercial tranche is not refinanced within five years, the lenders have the option to demand repayment. In October 2018, the maturity of the commercial tranche, and consequently the option to the lenders, was extended by five years, to 2024. ** This represents the total loan facilities drawn down by subsidiaries of ICBCL, CMBL, CCBFL, COSCO and CSSC, which we consider to be VIEs. See note 5.
Schedule of tranches	The facility is divided into three tranches, with the following general terms: Tranche Proportion of facility Term of loan from date of drawdown Repayment terms K-Sure 40% 12 years Six-monthly installments KEXIM 40% 12 years Six-monthly installments Commercial 20% 5 years Six-monthly installments, unpaid balance to be refinanced after 5 years

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	12 Months Ended
	Dec. 31, 2018
Payables and Accruals [Abstract]
Components of accrued expenses	(in thousands of $) 2018 2017 Vessel operating and drydocking expenses 24,041 10,978 Administrative expenses 11,042 9,572 Interest expense 97,688 84,249 Current tax payable 463 1,096 133,234 105,895

OTHER CURRENT LIABILITIES (Tabl

OTHER CURRENT LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2018
OTHER CURRENT LIABILITIES [Abstract]
Components of other current liabilities	(in thousands of $) 2018 2017 Deferred operating cost and charterhire revenue 8,206 1,044 Mark-to-market foreign exchange swaps valuation (see note 27) 1,322 223 Mark-to-market equity swaps valuation (see note 27) 70,804 40,141 Day 1 gain deferred revenue - current portion (see note 23) 9,950 7,463 Dividends payable 16,762 5,032 Other (1) 14,485 8,379 121,529 62,282 (1) This includes amounts owed to Keppel and B&V in relation to the Hilli Disposal.

OTHER NON-CURRENT LIABILITIES (

OTHER NON-CURRENT LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2018
OTHER LONG-TERM LIABILITIES [Abstract]
Components of other long-term liabilities	(in thousands of $) 2018 2017 Day 1 gain deferred revenue (1) 63,834 72,138 Deferred commissioning period revenue (2) 27,076 — Pension obligations (see note 24) 32,972 37,537 Guarantees issued to Golar Partners and Golar Power (see note 28) 14,770 11,429 Other (3) 6,912 11,444 145,564 132,548 (1) This represents the corresponding liability upon recognition of the LTA derivative asset. This deferred gain is amortized and recognized as part of "Liquefaction services revenue" in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli . The initial amount recognized was $79.6 million , of which $63.8 million is non-current at December 31, 2018 . The current portion of the Day 1 gain deferred revenue is included in "Other current liabilities" (see note 22). (2) This represents customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, which is considered an upfront payment for services. These amounts billed are recognized as part of "Liquefaction services revenue" in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli . The initial amount recognized was $33.8 million , of which $27.1 million is non-current at December 31, 2018 . The current portion of Deferred commissioning period billing is included in "Other current liabilities" (see note 22). (3) Included in "Other" is an asset retirement obligation of $4.4 million and $9.8 million for the years ended December 31, 2018 and 2017, respectively. The reduction of $5.4 million in the current year is as a result of a change in the estimated date on which the obligation will be settled, which resulted in a decrease of $5.6 million in the provision, partially offset by $0.2 million of accretion recognized for the current year ended December 31, 2018 . The corresponding asset of $4.4 million is recorded within vessels and equipment, net (see note 18).

PENSIONS (Tables)

PENSIONS (Tables)	12 Months Ended
	Dec. 31, 2018
Retirement Benefits [Abstract]
Components of net periodic benefit cost	The components of net periodic benefit costs are as follows: (in thousands of $) 2018 2017 2016 Service cost 250 313 302 Interest cost 1,687 1,901 2,051 Expected return on plan assets (926 ) (843 ) (806 ) Recognized actuarial loss 1,392 1,182 1,060 Net periodic benefit cost 2,403 2,553 2,607
Reconciliation of benefit obligation	The change in benefit obligation and plan assets and reconciliation of funded status as of December 31 are as follows: (in thousands of $) 2018 2017 Reconciliation of benefit obligation: Benefit obligation at January 1 51,171 50,376 Service cost 250 313 Interest cost 1,687 1,901 Actuarial (gain)/ loss (3,265 ) 873 Foreign currency exchange rate changes (599 ) 1,008 Benefit payments (3,151 ) (3,300 ) Benefit obligation at December 31 46,093 51,171
Reconciliation of fair value of plan assets	The accumulated benefit obligation at December 31, 2018 and 2017 was $45.3 million and $50.2 million , respectively. (in thousands of $) 2018 2017 Reconciliation of fair value of plan assets: Fair value of plan assets at January 1 13,634 12,503 Actual (loss)/ return on plan assets (249 ) 1,039 Employer contributions 3,617 2,316 Foreign currency exchange rate changes (730 ) 1,076 Benefit payments (3,151 ) (3,300 ) Fair value of plan assets at December 31 13,121 13,634 (in thousands of $) 2018 2017 Projected benefit obligation (46,093 ) (51,171 ) Fair value of plan assets 13,121 13,634 Unfunded status (1) (32,972 ) (37,537 )
Reconciliation of funded status	The details of these schemes are as follows: December 31, 2018 December 31, 2017 (in thousands of $) UK Scheme Marine Scheme Total UK Scheme Marine Scheme Total Projected benefit obligation (9,818 ) (36,275 ) (46,093 ) (11,654 ) (39,517 ) (51,171 ) Fair value of plan assets 12,291 830 13,121 12,968 666 13,634 Funded (unfunded) status at end of year 2,473 (35,445 ) (32,972 ) 1,314 (38,851 ) (37,537 )
Asset allocation of retirement schemes	The fair value of our plan assets, by category, as of December 31, 2018 and 2017 were as follows: (in thousands of $) 2018 2017 Equity securities 12,291 9,921 Debt securities — 3,047 Cash 830 666 13,121 13,634 The asset allocation for our Marine scheme at December 31, 2018 and 2017 , by asset category are as follows: Marine scheme 2018 (%) 2017 (%) Cash 100 10,000 Total 100 100 The asset allocation for our UK scheme at December 31, 2018 and 2017 , by asset category are as follows: UK scheme 2018 (%) 2017 (%) Equity 100 76.5 Bonds — 23.5 Total 100 100
Amounts recognized in accumulated other comprehensive income	The amounts recognized in accumulated other comprehensive income consist of: (in thousands of $) 2018 2017 Net actuarial loss (see note 26) 9,218 12,799 As at December 31, 2018 , 2017 and 2016 , our accumulated other comprehensive loss balances consisted of the following components: Pension and post retirement benefit plan adjustments Share of affiliates comprehensive (loss) income Total accumulated comprehensive (loss) income Balance at December 31, 2015 (12,400 ) (192 ) (12,592 ) Other comprehensive (loss) income (556 ) 3,606 3,050 Balance at December 31, 2016 (12,956 ) 3,414 (9,542 ) Other comprehensive income 157 1,616 1,773 Balance at December 31, 2017 (12,799 ) 5,030 (7,769 ) Other comprehensive income (loss) 3,581 (24,324 ) (20,743 ) Balance at December 31, 2018 (9,218 ) (19,294 ) (28,512 )
Expected contributions to pension schemes	We are expected to make the following contributions to the schemes during the year ended December 31, 2019, as follows: (in thousands of $) UK scheme Marine scheme Employer contributions 510 2,900
Expected pension disbursements	We are expected to make the following pension disbursements as follows: (in thousands of $) UK scheme Marine scheme 2019 330 3,000 2020 410 3,000 2021 535 3,000 2022 355 3,000 2023 370 3,000 2024 - 2028 2,310 12,500
Weighted average assumptions used	The weighted average assumptions used to determine the benefit obligation for our plans for the years ended December 31 are as follows: 2018 2017 Discount rate 3.90 % 3.40 % Rate of compensation increase 2.20 % 2.32 % The weighted average assumptions used to determine the net periodic benefit cost for our plans for the years ended December 31 are as follows: 2018 2017 Discount rate 3.40 % 3.87 % Expected return on plan assets 6.75 % 6.75 % Rate of compensation increase 2.32 % 2.38 %

SHARE CAPITAL AND SHARE OPTIO_2

SHARE CAPITAL AND SHARE OPTIONS (Tables)	12 Months Ended
	Dec. 31, 2018
SHARE CAPITAL AND SHARE OPTIONS [Abstract]
Authorized and issue share capital	As at December 31, 2018 and 2017 , our authorized and issued share capital is as follows: Authorized share capital: (in thousands of $, except per share data) 2018 2017 150,000,000 (2017: 150,000,000) common shares of $1.00 each 150,000 150,000 Issued share capital: (in thousands of $, except per share data) 2018 2017 101,302,404 (2017: 101,118,289) outstanding issued common shares of $1.00 each 101,303 101,119
Weighted average assumptions used	The weighted average assumptions as at grant date are noted in the table below: 2018 2017 2016 Risk free interest rate 2.5 % 1.8 % 1.8 % Expected volatility of common stock 62.5 % 54.5 % 55.0 % Expected dividend yield 0.0 % 0.0 % 0.0 % Expected term of options (in years) 3.6 years 3.8 years 5.0 years
Summary of stock option activity	Year ended December 31 In $'000 2018 2017 2016 Intrinsic value of share options exercised 2,621 286 1,326 Total fair value of share options fully vested in the year 16,623 13,601 113 Compensation cost recognized in the consolidated statement of operations 11,748 8,777 5,830 Share options cost capitalized* 421 1,823 822 * These costs have been capitalized as part of the cost of the conversion of the Hilli, representing share options awarded to employees directly involved in the conversion. A summary of option activity as at December 31, 2018 is presented below: (in thousands of $, except per share data) Shares (in '000s) Weighted average exercise price Weighted average remaining contractual term (years) Options outstanding at December 31, 2017 4,017 $ 37.92 3.0 Exercised during the year (184 ) $ 14.60 Forfeited during the year (521 ) $ 45.06 Lapsed during the year (15 ) $ 31.46 Granted during the year 508 $ 27.20 Options outstanding at December 31, 2018 3,805 $ 36.16 2.4 Options exercisable at: December 31, 2018 2,320 $ 39.02 1.96 December 31, 2017 1,139 $ 37.92 2.53 December 31, 2016 108 $ 2.84 0.83

ACCUMULATED OTHER COMPREHENSI_2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	12 Months Ended
	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Amounts recognized in accumulated other comprehensive income	The amounts recognized in accumulated other comprehensive income consist of: (in thousands of $) 2018 2017 Net actuarial loss (see note 26) 9,218 12,799 As at December 31, 2018 , 2017 and 2016 , our accumulated other comprehensive loss balances consisted of the following components: Pension and post retirement benefit plan adjustments Share of affiliates comprehensive (loss) income Total accumulated comprehensive (loss) income Balance at December 31, 2015 (12,400 ) (192 ) (12,592 ) Other comprehensive (loss) income (556 ) 3,606 3,050 Balance at December 31, 2016 (12,956 ) 3,414 (9,542 ) Other comprehensive income 157 1,616 1,773 Balance at December 31, 2017 (12,799 ) 5,030 (7,769 ) Other comprehensive income (loss) 3,581 (24,324 ) (20,743 ) Balance at December 31, 2018 (9,218 ) (19,294 ) (28,512 )

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Interest rate derivatives	As of December 31, 2018 and 2017 , we were party to the following interest rate swap transactions involving the payment of fixed rates in exchange for LIBOR as summarized below: Instrument (in thousands of $) Year end Notional value Maturity dates Fixed interest rates Interest rate swaps * : Receiving floating, pay fixed 2018 950,000 2019/ 2021 1.23% to 1.94% Receiving floating, pay fixed 2017 1,250,000 2018/ 2021 1.13% to 1.94% * This excludes any interest rate swap agreements designated and qualifying cash flow hedges in our equity method investments.
Fair value hierarchy of derivative and non-derivative financial instruments	The carrying value and fair value of our financial instruments at December 31, 2018 and 2017 are as follows: 2018 2018 2017 2017 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-derivatives: Cash and cash equivalents Level 1 217,835 217,835 214,862 214,862 Restricted cash and short-term deposits Level 1 486,426 486,426 397,815 397,815 Current portion of long-term debt and short-term debt (1)(2) Level 2 (732,184 ) (732,184 ) (1,393,229 ) (1,393,229 ) Long-term debt – convertible bonds (2) Level 2 (353,661 ) (373,029 ) (340,173 ) (430,361 ) Long-term debt (2) Level 2 (1,496,351 ) (1,496,351 ) (701,498 ) (701,498 ) Derivatives: Oil derivative instrument (6) Level 2 84,730 84,730 94,700 94,700 Interest rate swaps asset (3) Level 2 10,770 10,770 10,166 10,166 Foreign exchange swaps asset (3) Level 2 — — 51 51 Foreign exchange swaps liability (3) Level 2 (1,322 ) (1,322 ) (223 ) (223 ) Total return equity swap liability (3)(4) Level 2 (70,804 ) (70,804 ) (40,141 ) (40,141 ) Earn-Out Units asset (5) Level 2 — — 7,400 7,400 (1) The carrying amounts of our short-term debts and loans receivable approximate their fair values because of the near term maturity of these instruments. (2) Our debt obligations are recorded at amortized cost in the consolidated balance sheets. The amounts presented in the table, are gross of the deferred charges amounting to $ 16.8 million and $ 24.1 million at December 31, 2018 and December 31, 2017 , respectively. (3) The fair value of certain derivative instruments is the estimated amount that we would receive or pay to terminate the agreements at the reporting date, taking into account current interest rates, foreign exchange rates, closing quoted market prices and our creditworthiness and that of our counterparties. (4) The fair value of total return equity swaps is calculated using the closing prices of the underlying listed shares, dividends paid since inception and the interest rate charged by the counterparty. (5) The Earn-Out Units were issued to Golar in connection with the IDR Reset transaction between Golar and Golar Partners in October 2016. In October 2018, Golar Partners reduced their quarterly distribution and, as such, the fair value of the Earn-Out Units was written down to $ nil . See note 16. (6) The fair value of the oil derivative instrument was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA. Significant inputs used in the valuation of the oil derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets.
Summary of fair value of derivative instruments on a gross basis	The following table summarizes the fair value of our derivative instruments on a gross basis (none of which have been designated as hedges) recorded in our consolidated balance sheets as of December 31, 2018 and 2017: Balance sheet classification 2018 2017 (in thousands of $) Asset derivatives Oil derivative instrument Other non-current assets 84,730 94,700 Earn-Out Units asset Other non-current assets — 7,400 Interest rate swaps Other current and non-current assets 10,770 10,166 Foreign exchange swaps Other non-current assets — 51 Total asset derivatives 95,500 112,317 Liability derivatives Foreign exchange swaps Other current liabilities 1,322 223 Total return equity swap Other current liabilities 70,804 40,141 Total liability derivatives 72,126 40,364
Offsetting assets	We have elected not to offset the fair values of derivative assets and liabilities executed with the same counterparty that are generally subject to enforceable master netting arrangements. However, if we were to offset and record the asset and liability balances of derivatives on a net basis, the amounts presented in our consolidated balance sheets as of December 31, 2018 and 2017 would be adjusted as detailed in the following table: 2018 2017 Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount (in thousands of $) Total asset derivatives 10,770 — 10,770 10,166 — 10,166

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2018
Related Party Transactions [Abstract]
Related party transactions	The transactions with OneLNG and its subsidiaries for the year ended December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 2016 Management and administrative services revenue 1,399 6,463 586 Receivables: The balances with OneLNG and its subsidiaries as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances due from OneLNG (i) 8,169 7,898 (i) Trading balances - Receivables and payables with One LNG and its subsidiaries are comprised primarily of unpaid management fees, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from OneLNG are unsecured, interest-free and intended to be settled in the ordinary course of business. The transactions with Golar Power and its affiliates for the twelve months ended December 31, 2018 , 2017 and 2016 consisted of the following: (in thousands of $) 2018 2017 2016 Management and administrative services revenue 6,167 5,711 1,965 Ship management fees income 1,400 824 335 Debt guarantee compensation (i) 861 775 488 Other (247 ) 135 — Total 8,181 7,445 2,788 Payables: The balances with Golar Power and its affiliates as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances due to Golar Power and affiliates (ii) (5,417 ) (935 ) Total (5,417 ) (935 ) (i) Debt guarantee compensation - In connection with the closing of the Golar Power and Stonepeak transaction, Golar Power entered into agreements to compensate Golar in relation to certain debt guarantees (as further described under the subheading "Guarantees and other") relating to Golar Power and subsidiaries. This compensation amounted to an aggregate of $0.9 million and $0.8 million income for the year ended December 31, 2018 and 2017 , respectively. (ii) Trading balances - Receivables and payables with Golar Power and its subsidiaries are comprised primarily of unpaid management fees, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Power and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. Transactions with Golar Partners and subsidiaries: Income (expenses): (in thousands of $) 2018 2017 2016 Management and administrative services revenue (i) 9,809 7,762 4,251 Ship management fees revenue (ii) 5,200 5,903 6,466 Charterhire expenses (iii) — (17,423 ) (28,368 ) Interest expense on short-term credit facility (iv) — — (122 ) Share options expense recharge (vi) — 228 181 Interest expense on deposits payable (vii) (4,779 ) (4,622 ) (1,967 ) Total 10,230 (8,152 ) (19,559 ) Receivables (payables): The balances with Golar Partners and subsidiaries as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 Trading balances owed from/ (to) Golar Partners and subsidiaries (iv) 4,091 (4,144 ) Methane Princess lease security deposit movements (v) (2,835 ) (3,464 ) Deposit payable (vii) — (177,247 ) Total 1,256 (184,855 ) (i) Management and administrative services agreement - On March 30, 2011, Golar Partners entered into a management and administrative services agreement with Golar Management, a wholly-owned subsidiary of Golar, pursuant to which Golar Management will provide to Golar Partners certain management and administrative services. The services provided by Golar Management are charged at cost plus a management fee equal to 5% of Golar Management’s costs and expenses incurred in connection with providing these services. Golar Partners may terminate the agreement by providing 120 days written notice. (ii) Ship management fees - Golar and certain of its affiliates charge ship management fees to Golar Partners for the provision of technical and commercial management of Golar Partners' vessels. Each of Golar Partners’ vessels is subject to management agreements pursuant to which certain commercial and technical management services are provided by Golar Management. Golar Partners may terminate these agreements by providing 30 days written notice. (iii) Charterhire expenses - This consists of the charterhire expenses that we incurred for the charter back from Golar Partners of the Golar Grand in 2015, 2016 and 2017. On November 1, 2017, the Golar Grand guarantee concluded. In connection with the sale of the Golar Grand to Golar Partners in November 2012, we issued an option where, in the event that the charterer did not renew or extend its charter for the Golar Grand beyond February 2015, the Partnership had the option to require us to charter the vessel through to October 2017. In February 2015, the option was exercised. Accordingly, we recognized charterhire costs of $17.4 million and $28.4 million for the year ended December 31, 2017 and 2016, respectively, in relation to the Golar Grand. The above disclosure excludes the net effect of the non-cash credit of $5.1 million and $6.1 million for the year ended December 31, 2017 and 2016, respectively. This relates to the Golar Grand guarantee obligation, which includes recognition of a loss on remeasurement in 2017, less amortization of the guarantee obligation. The Golar Grand guarantee concluded on November 2017. (iv) Trading balances - Receivables and payables with Golar Partners and its subsidiaries are comprised primarily of unpaid management fees and expenses for management, advisory and administrative services and may include working capital adjustments in respect of disposals to the Partnership, as well as charterhire expenses. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Partners and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. They primarily relate to recharges for trading expenses paid on behalf of Golar Partners, including ship management and administrative service fees due to us. In January 2016, we received funding from Golar Partners in the amount of $30 million for a fixed period of 60 days. Golar Partners charged interest on this balance at a rate of LIBOR plus 5.0% . (v) Methane Princess lease security deposit movements - This represents net advances from Golar Partners since its IPO, which correspond with the net release of funds from the security deposits held relating to a lease for the Methane Princess . This is in connection with the Methane Princess tax lease indemnity provided to Golar Partners under the Omnibus Agreement. Accordingly, these amounts will be settled as part of the eventual termination of the Methane Princess lease. (vi) Share options expense - This relates to a recharge of share option expense to Golar Partners in relation to share options in Golar granted to certain of Golar Partners' directors, officers and employees. (vii) Interest expense on deposits payable Expense under Tundra Letter Agreement - In May 2016, we completed the Golar Tundra Sale and received a total cash consideration of $107.2 million . We agreed to pay Golar Partners a daily fee plus operating expenses for the right to use the Golar Tundra from the date the Golar Tundra Sale was closed, until the date that the vessel would commence operations under the Golar Tundra Time Charter. In return, Golar Partners agreed to remit to us any hire income received with respect to the Golar Tundra during that period. It was further agreed that, if for any reason the Golar Tundra Time Charter had not commenced by the 12 month anniversary of the closing of the Golar Tundra Sale, Golar Partners had the right to require that we repurchase the shares of Tundra Corp at a price equal to the purchase price. Accordingly, by virtue of the put option, we continued to consolidate the Golar Tundra for the periods whilst the put option remained in place, thus we have accounted for $ nil , $2.2 million and $2.0 million as interest expense for the year ended December 31, 2018, 2017 and 2016, respectively. Deferred purchase price - In May 2017, the Golar Tundra had not commenced her charter and, accordingly, Golar Partners elected to exercise the Tundra Put Right to require us to repurchase Tundra Corp at a price equal to the original purchase price. In connection with Golar Partners exercising the Tundra Put Right, we and Golar Partners entered into an agreement pursuant to which we agreed to purchase Tundra Corp from Golar Partners on the date of the closing of the Tundra Put Sale (the "Put Sale Closing Date") in return we will be required to pay an amount equal to $107.2 million (the "Deferred Purchase Price") plus an additional amount equal to 5% per annum of the Deferred Purchase Price (the "Additional Amount"). The Deferred Purchase Price and the Additional Amount shall be due and payable by us on the earlier of (a) the date of the closing of the Hilli Disposal (see below) and (b) March 31, 2018. We agreed to accept the Deferred Purchase Price and the Additional Amount in lieu of a cash receipt on the Put Sale Closing Date in return we have provided Golar Partners with an option (which Golar Partners have exercised) to purchase an interest in Hilli Corp. We have accounted for $2.9 million and $1.1 million as interest expense for the year ended December 31, 2018 , and 2017 , respectively, in relation to the Deferred Purchase Price. Deposit received from Golar Partners - On August 15, 2017, we entered into a purchase and sale agreement (the "Hilli Sale Agreement") with Golar Partners for the disposal (the "Hilli Disposal") from Golar and affiliates of Keppel and Black & Veatch of common units (the "Disposal Interests") in Golar Hilli LLC. On the closing date of the Hilli Disposal, Golar Hilli LLC will indirectly (via its wholly-owned subsidiary) be the disponent owner of the Hilli . The Disposal Interests represent the equivalent of 50% of the two liquefaction trains, out of a total of four, that are contracted to the Perenco and SNH under an eight -year LTA. The sale price for the Disposal Interests is $658 million less 50% of the net lease obligations under the financing facility for the Hilli (the "Hilli Facility"), on closing date, plus post-closing purchase price adjustments. Concurrently with the execution of the Hilli Sale Agreement, we received a further $70 million deposit from Golar Partners, upon which we pay interest at a rate of 5% per annum. We have accounted for $1.9 million and $1.3 million as interest expense for the year ended December 31, 2018 , and 2017 , respectively, in relation to the $70 million deposit from Golar Partners. The transactions with other related parties for the years ended December 31, 2018 , 2017 and 2016 consisted of the following: (in thousands of $) 2018 2017 2016 The Cool Pool (i) 151,152 59,838 32,254 Magni Partners (ii) (375 ) (260 ) (4,282 ) Total 150,777 59,578 27,972 Receivables (Payables): The balances with other related parties as of December 31, 2018 and 2017 consisted of the following: (in thousands of $) 2018 2017 The Cool Pool (i) 43,985 14,004 Magni Partners (ii) (8 ) 6 Total 43,977 14,010 (i) The Cool Pool - For the year ended December 31, 2018 we recognized net income of $151.2 million from our participation in the Cool Pool. Trade accounts receivable includes amounts due from the Cool Pool, amounting to $44.0 million as of December 31, 2018 (December 31, 2017 : $14.0 million ). The table below summarizes our net earnings (impacting each line item in our consolidated statement of operations) generated from our participation in the Cool Pool: (in thousands of $) 2018 2017 2016 Time and voyage charter revenues 177,139 77,975 37,345 Time charter revenues - collaborative arrangement 73,931 28,327 13,730 Voyage, charterhire expenses and commission expenses (16,717 ) (7,683 ) (7,681 ) Voyage, charterhire and commission expenses - collaborative arrangement (83,201 ) (38,781 ) (11,140 ) Net income from the Cool Pool 151,152 59,838 32,254 (ii) Magni Partners - Tor Olav Trøim is the founder of, and partner in, Magni Partners Limited, a privately held UK company, and is the ultimate beneficial owner of the company. Pursuant to an agreement between Magni Partners Limited and a Golar subsidiary, for the year ended December 31, 2018 and 2017, Golar was recharged $0.4 million and $0.3 million , respectively, for services provided on behalf of our affiliates. In December 31, 2016, Golar was recharged $3.9 million (this includes $3.0 million in relation to the transaction with Golar Power, which has been recorded as part of the loss on disposal of Golar Power in the income statement) for advisory services from a partner and director of Magni Partners Limited, other than Mr Trøim. In addition, for the year ended December 31, 2018 and 2017 Golar was recharged $0.04 million and $0.3 million , respectively, for travel relating to certain board members. Furthermore, for the year ended December 31, 2017 Golar was recharged $0.3 million for other travel and out of pocket expenses. All charges have been recharged to Golar at cost.

CAPITAL COMMITMENTS CAPITAL COM

CAPITAL COMMITMENTS CAPITAL COMMITMENTS (Tables)	12 Months Ended
	Dec. 31, 2018
CAPITAL COMMITMENTS [Abstract]
Purchase Obligations	As at December 31, 2018 , the estimated timing of the outstanding payments in connection with the Limited Notice to Proceed on the Gimi conversion are as follows: (in thousands of $) Payable within 12 months to December 31, 2019 21,530 21,530

OTHER COMMITMENTS AND CONTING_2

OTHER COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Assets pledged as collateral	Assets pledged (in thousands of $) 2018 2017 Book value of vessels secured against long-term loans 3,244,291 2,032,747

GENERAL - Narrative (Details)

GENERAL - Narrative (Details) $ in Millions	Feb. 26, 2019	Feb. 28, 2019USD ($)	Feb. 27, 2019USD ($)	Dec. 31, 2018vessel
Ownership interests:
Number of carriers operated by other				16
LNG carrier | Golar Partners
Ownership interests:
Number of carriers operated by other				10
LNG carrier | Golar Power
Ownership interests:
Number of carriers operated by other				3
LNG carrier | Vessels and equipment
Ownership interests:
Number of carriers owned and operated				12
LNG carrier | Vessels and equipment | Golar LNG Limited, Golar LNG Partners, and Golar Power
Ownership interests:
Number of carriers owned and operated				18
FSRU | Vessels and equipment
Ownership interests:
Number of carriers owned and operated				1
FSRU | Vessels and equipment | Golar LNG Limited, Golar LNG Partners, and Golar Power
Ownership interests:
Number of carriers owned and operated				8
Vessels - FLNG | Vessels and equipment
Ownership interests:
Number of carriers owned and operated				1
Vessels - FLNG | Vessels and equipment | Golar LNG Limited, Golar LNG Partners, and Golar Power
Ownership interests:
Number of carriers owned and operated				1
Subsequent Event | Keppel Capital
Ownership interests:
Long-term purchase commitment, percentage	30.00%
Gimi Conversion | Subsequent Event
Ownership interests:
Long-term purchase commitment, period		20 years
Long-term purchase commitment, amount | $		$ 1,300
Expected future revenues, net of operating costs | $		$ 215
Long-term line of credit | $			$ 700

BASIS OF PREPARATION AND SIGN_4

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES - Gain (Loss) Derivative Instruments (Details) - Vessels - FLNG - Energy Related Derivative - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Price Risk Derivatives [Line Items]
Realized gain on oil derivative instrument	$ 26,737	$ 0
Unrealized (loss) gain on oil derivative instrument	(9,970)	15,100
Gain (loss) on price risk derivatives, net	$ 16,767	$ 15,100

BASIS OF PREPARATION AND SIGN_5

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Details)	12 Months Ended
	Dec. 31, 2018segmentvessel
Trading activity:
Percentage of voting interest acquired	50.00%
Number of vessels in sale and leaseback transaction | vessel	8
Number of reportable segments | segment	3
Drydocking
Trading activity:
Period until next anticipated drydocking	5 years

BASIS OF PREPARATION AND SIGN_6

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES - Property and Equipment (Details)	12 Months Ended
	Dec. 31, 2018
Vessels (excluding converted FSRUs and FLNG)
Property and equipment:
Useful lives applied in depreciation	40 years
Vessels - converted FSRUs
Property and equipment:
Useful lives applied in depreciation	20 years
Vessels - FLNG
Property and equipment:
Useful lives applied in depreciation	30 years
Drydocking expenditure
Property and equipment:
Useful lives applied in depreciation	5 years
Deferred drydocking expenditure - FLNG
Property and equipment:
Useful lives applied in depreciation	20 years
Mooring equipment - FLNG
Property and equipment:
Useful lives applied in depreciation	8 years
Minimum | Office equipment and fittings
Property and equipment:
Useful lives applied in depreciation	3 years
Maximum | Office equipment and fittings
Property and equipment:
Useful lives applied in depreciation	6 years

BASIS OF PREPARATION AND SIGN_7

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES - Project Development Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses	$ 51,542	$ 38,031	$ 37,302
Project development expenses	$ 21,690	12,303	8,658
Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses		50,334	45,960
Project development expenses		0	0
Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses		(12,303)	(8,658)
Project development expenses		$ 12,303	$ 8,658

BASIS OF PREPARATION AND SIGN_8

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES - Changes in Presentation of Derivative Instruments (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments		$ 38,610	$ (24,498)	$ (26,644)
Other current and non-current assets		(13,532)	(80,897)	14,615
Other current and non-current liabilities	[1]	40,164	99,886	9,680
(Losses) gains on derivative instruments		(30,541)	20,696	16,491
Other financial items, net		(1,481)	(69)	(7,800)
Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments			0	0
Other current and non-current assets			(102,453)	14,924
Other current and non-current liabilities			81,844	(17,273)
(Losses) gains on derivative instruments			0	0
Other financial items, net			20,627	8,691
Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments			(24,498)	(26,644)
Other current and non-current assets			21,556	(309)
Other current and non-current liabilities			18,042	26,953
(Losses) gains on derivative instruments			20,696	16,491
Other financial items, net			(20,696)	(16,491)
Energy Related Derivative
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments		$ 9,970	(15,100)	$ 0
Energy Related Derivative | Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments			0
Energy Related Derivative | Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in fair value of derivative instruments			$ (15,100)
[1]	Includes accretion of discount on convertible bonds of $13.5 million, $11.8 million and $5.7 million for the years ended December 31, 2018, 2017 and 2016, respectively.

RECENTLY ISSUED ACCOUNTING ST_3

RECENTLY ISSUED ACCOUNTING STANDARDS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities		$ 0	$ 0
Increase (decrease) in restricted cash and cash equivalents, investing activities		0	0
Increase (decrease) in restricted cash and cash equivalents, financing activities		0	0
Net (decrease) increase in cash, cash equivalents and restricted cash	$ 91,584	(27,541)	122,801
Cash, cash equivalents and restricted cash at beginning of period	612,677	640,218	517,417
Cash, cash equivalents and restricted cash at end of period	704,261	612,677	640,218
Accounting Standards Update 2016-15
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect of new accounting principle in period of adoption		25,100	29,000
Accounting Standards Update 2016-18 | Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities		57,110	47,834
Increase (decrease) in restricted cash and cash equivalents, investing activities		11,239	22,928
Increase (decrease) in restricted cash and cash equivalents, financing activities		(50,136)	(74,608)
Net (decrease) increase in cash, cash equivalents and restricted cash		(9,328)	118,955
Cash, cash equivalents and restricted cash at beginning of period	214,862	224,190	105,235
Cash, cash equivalents and restricted cash at end of period		214,862	224,190
Accounting Standards Update 2016-18 | Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities		(57,110)	(47,834)
Increase (decrease) in restricted cash and cash equivalents, investing activities		(11,239)	(22,928)
Increase (decrease) in restricted cash and cash equivalents, financing activities		50,136	74,608
Net (decrease) increase in cash, cash equivalents and restricted cash		(18,213)	3,846
Cash, cash equivalents and restricted cash at beginning of period	$ 397,815	416,028	412,182
Cash, cash equivalents and restricted cash at end of period		$ 397,815	$ 416,028

SUBSIDIARIES - Narrative (Detai

SUBSIDIARIES - Narrative (Details)	Dec. 31, 2018
Ownership interests:
Subsidiary ownership percentage	100.00%
Golar LNG 2216 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Management Limited
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Management Malaysia Sdn. Bhd.
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Management Norway AS
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Management D.O.O.
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar GP LLC – Limited Liability Company
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar LNG Energy Limited
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Gimi Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hilli Corporation
Ownership interests:
Percentage ownership in subsidiary	89.00%
Golar Gandria N.V.
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hull M2021 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hull M2022 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hull M2027 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hull M2047 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hull M2048 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar LNG NB10 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar LNG NB11 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar LNG NB12 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar LNG NB13 Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
GVS Corporation
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Shoreline LNG Limited
Ownership interests:
Percentage ownership in subsidiary	100.00%
Golar Hilli LLC
Ownership interests:
Percentage ownership in subsidiary	100.00%

VARIABLE INTEREST ENTITIES ("_3

VARIABLE INTEREST ENTITIES ("VIE") - Narrative (Details) $ in Thousands	3 Months Ended	6 Months Ended	12 Months Ended
	Mar. 31, 2015newbuild	Dec. 31, 2018USD ($)	Dec. 31, 2018USD ($)vessel	Dec. 31, 2017USD ($)vessel	Dec. 31, 2016USD ($)
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			8
Interest expense			$ 101,908	$ 59,305	$ 71,201
Net cash received in financing activities			177,402	427,443	234,336
Total operating revenues			430,604	143,537	80,257
Realized and unrealized gain on oil derivative instrument			$ 16,767	$ 15,100	0
CMBL Lessor VIE | Golar Tundra
Variable Interest Entity [Line Items]
Term of sale leaseback transaction			10 years
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			8	7
Interest expense			$ 61,500	$ 37,400	44,100
Net cash received in financing activities			$ 761,200	51,500	154,200
Variable Interest Entity, Primary Beneficiary | ICBC Finance Leasing Co. Ltd Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			4
Number of newbuilds in sale and leaseback transaction | newbuild	3
Term of sale leaseback transaction			10 years
Variable Interest Entity, Primary Beneficiary | CMBL Lessor VIE
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			1
Term of sale leaseback transaction			10 years
Variable Interest Entity, Primary Beneficiary | CCBFL Lessor Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			1
Variable Interest Entity, Primary Beneficiary | CCBFL Lessor Agreement | Golar Seal
Variable Interest Entity [Line Items]
Term of sale leaseback transaction			10 years
Variable Interest Entity, Primary Beneficiary | COSCO Shipping Lessor Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			1
Variable Interest Entity, Primary Beneficiary | COSCO Shipping Lessor Agreement | Golar Crystal
Variable Interest Entity [Line Items]
Term of sale leaseback transaction			10 years
Variable Interest Entity, Primary Beneficiary | China State Shipbuilding Corporation, CSSC
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction | vessel			1
Variable Interest Entity, Primary Beneficiary | China State Shipbuilding Corporation, CSSC | Hilli
Variable Interest Entity [Line Items]
Term of sale leaseback transaction			10 years
Liquefaction Services
Variable Interest Entity [Line Items]
Total operating revenues			$ 127,625	$ 0	$ 0
Liquefaction Services | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Net cash received in financing activities		$ (30,300)

VARIABLE INTEREST ENTITIES ("_4

VARIABLE INTEREST ENTITIES ("VIE") - Summary of the Sale and Leaseback Arrangement (Details) - Variable Interest Entity, Primary Beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
ICBC Finance Leasing Co. Ltd Agreement | Golar Glacier
Variable Interest Entity [Line Items]
Sales value	$ 204
First repurchase option	173.8
Repurchase obligation at end of lease term	135.1
ICBC Finance Leasing Co. Ltd Agreement | Golar Kelvin
Variable Interest Entity [Line Items]
Sales value	204
First repurchase option	173.8
Repurchase obligation at end of lease term	135.1
ICBC Finance Leasing Co. Ltd Agreement | Golar Snow
Variable Interest Entity [Line Items]
Sales value	204
First repurchase option	173.8
Repurchase obligation at end of lease term	135.1
ICBC Finance Leasing Co. Ltd Agreement | Golar Ice
Variable Interest Entity [Line Items]
Sales value	204
First repurchase option	173.8
Repurchase obligation at end of lease term	135.1
CMBL Lessor VIE | Golar Tundra
Variable Interest Entity [Line Items]
Sales value	254.6
First repurchase option	168.7
Repurchase obligation at end of lease term	76.4
CCBFL Lessor Agreement | Golar Seal
Variable Interest Entity [Line Items]
Sales value	203
First repurchase option	132.8
Repurchase obligation at end of lease term	87.4
COSCO Shipping Lessor Agreement | Golar Crystal
Variable Interest Entity [Line Items]
Sales value	187
First repurchase option	97.3
Repurchase obligation at end of lease term	50.6
China State Shipbuilding Corporation, CSSC | Hilli
Variable Interest Entity [Line Items]
Sales value	1,200
First repurchase option	633.2
Repurchase obligation at end of lease term	$ 300

VARIABLE INTEREST ENTITIES ("_5

VARIABLE INTEREST ENTITIES ("VIE") - Summary of Bareboat Charters (Details) - Variable Interest Entity, Primary Beneficiary $ in Thousands	Dec. 31, 2018USD ($)
ICBC Finance Leasing Co. Ltd Agreement | Golar Glacier
Variable Interest Entity [Line Items]
2019	$ 17,100
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024 and thereafter	12,884
ICBC Finance Leasing Co. Ltd Agreement | Golar Kelvin
Variable Interest Entity [Line Items]
2019	17,100
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024 and thereafter	15,695
ICBC Finance Leasing Co. Ltd Agreement | Golar Snow
Variable Interest Entity [Line Items]
2019	17,100
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024 and thereafter	15,695
ICBC Finance Leasing Co. Ltd Agreement | Golar Ice
Variable Interest Entity [Line Items]
2019	17,100
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024 and thereafter	18,599
CMBL Lessor VIE | Golar Tundra
Variable Interest Entity [Line Items]
2019	22,437
2020	21,548
2021	20,610
2022	19,697
2023	18,784
2024 and thereafter	32,079
CCBFL Lessor Agreement | Golar Seal
Variable Interest Entity [Line Items]
2019	13,754
2020	13,717
2021	13,717
2022	13,717
2023	13,754
2024 and thereafter	27,433
COSCO Shipping Lessor Agreement | Golar Crystal
Variable Interest Entity [Line Items]
2019	12,441
2020	12,335
2021	12,175
2022	12,050
2023	11,907
2024 and thereafter	37,601
China State Shipbuilding Corporation, CSSC | Hilli
Variable Interest Entity [Line Items]
2019	128,418
2020	123,526
2021	118,800
2022	114,075
2023	109,463
2024 and thereafter	$ 412,055

VARIABLE INTEREST ENTITIES ("_6

VARIABLE INTEREST ENTITIES ("VIE") - Summary of assets and liabilities of lessor VIEs (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Variable Interest Entity [Line Items]
Restricted cash	$ 486,426	$ 397,815
Long-term interest bearing debt - non-current portion	1,835,102	1,025,914
Total liabilities	2,980,804	2,967,983
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Restricted cash	176,428	130,063
Short-term interest bearing debt	646,513	833,664
Long-term interest bearing debt - non-current portion	1,200,774	252,691
Total liabilities	1,847,287	$ 1,086,355
ICBC Finance Leasing Co. Ltd Agreement | Variable Interest Entity, Primary Beneficiary | Golar Glacier
Variable Interest Entity [Line Items]
Restricted cash	21,170
Short-term interest bearing debt	39,319
Long-term interest bearing debt - non-current portion	114,093
Total liabilities	153,412
ICBC Finance Leasing Co. Ltd Agreement | Variable Interest Entity, Primary Beneficiary | Golar Kelvin
Variable Interest Entity [Line Items]
Restricted cash	71,924
Short-term interest bearing debt	182,540
Long-term interest bearing debt - non-current portion	0
Total liabilities	182,540
ICBC Finance Leasing Co. Ltd Agreement | Variable Interest Entity, Primary Beneficiary | Golar Snow
Variable Interest Entity [Line Items]
Restricted cash	19,294
Short-term interest bearing debt	30,404
Long-term interest bearing debt - non-current portion	123,267
Total liabilities	153,671
ICBC Finance Leasing Co. Ltd Agreement | Variable Interest Entity, Primary Beneficiary | Golar Ice
Variable Interest Entity [Line Items]
Restricted cash	8
Short-term interest bearing debt	117,888
Long-term interest bearing debt - non-current portion	0
Total liabilities	117,888
CMBL Lessor VIE | Variable Interest Entity, Primary Beneficiary | Golar Tundra
Variable Interest Entity [Line Items]
Restricted cash	0
Short-term interest bearing debt	121,741
Long-term interest bearing debt - non-current portion	0
Total liabilities	121,741
CCBFL Lessor Agreement | Variable Interest Entity, Primary Beneficiary | Golar Seal
Variable Interest Entity [Line Items]
Restricted cash	3,405
Short-term interest bearing debt	0
Long-term interest bearing debt - non-current portion	123,524
Total liabilities	123,524
COSCO Shipping Lessor Agreement | Variable Interest Entity, Primary Beneficiary | Golar Crystal
Variable Interest Entity [Line Items]
Restricted cash	3,186
Short-term interest bearing debt	5,741
Long-term interest bearing debt - non-current portion	90,790
Total liabilities	96,531
China State Shipbuilding Corporation, CSSC | Variable Interest Entity, Primary Beneficiary | Hilli
Variable Interest Entity [Line Items]
Restricted cash	57,441
Short-term interest bearing debt	148,880
Long-term interest bearing debt - non-current portion	749,100
Total liabilities	$ 897,980

VARIABLE INTEREST ENTITIES ("_7

VARIABLE INTEREST ENTITIES ("VIE") - Summary of Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 217,835	$ 214,862	$ 224,190	$ 105,235
Restricted cash and short-term deposits	332,033	222,265	183,693	$ 231,821
Vessels and equipment, net	3,271,379	2,077,059
Other non-current assets	139,104	157,504
Total assets	4,806,595	4,764,287	$ 4,256,911
Liabilities [Abstract]
Long-term interest bearing debt - non-current portion	1,835,102	1,025,914
Total liabilities	2,980,804	$ 2,967,983
Golar Hilli LLC | Golar Partners | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
ASSETS
Cash and cash equivalents	85,238
Restricted cash and short-term deposits	57,441
Vessels and equipment, net	1,301,279
Other non-current assets	91,431
Total assets	1,535,389
Liabilities [Abstract]
Current portion of long-term debt and short-term debt	148,880
Long-term interest bearing debt - non-current portion	749,100
Total liabilities	$ 897,980

DISPOSAL OF LONG-LIVED ASSETS -

DISPOSAL OF LONG-LIVED ASSETS - Partial Disposal of the Hilli (Details) $ in Thousands	Jul. 12, 2018USD ($)shares	Dec. 31, 2018USD ($)$ / barrel	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Schedule of Equity Method Investments [Line Items]
Net loss attributable to stockholders of Golar LNG Limited		$ (231,428)	$ (179,703)	$ (186,531)
Transfer to noncontrolling interest		304,468
Changes in net income and transfers to non-controlling interest		$ 73,040
Oil price per barrel | $ / barrel		60
Golar, Keppel, and B&V | Golar Hilli LLC | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Purchase price	$ 658,000
Portion of net lease obligations	50.00%
Related Party, Deposit Amount Incl. Accrued Interest | Golar, Keppel, and B&V | Golar Hilli LLC | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Deposit received	$ 71,900
Golar Tundra | Related Party, Deposit Amount Incl. Accrued Interest | Golar Partners
Schedule of Equity Method Investments [Line Items]
Deposit received	$ 110,100
Common Units | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	44.60%
Entitlement to distributions		5.00%
Entitlement to vehicle expansion capacity distributions		5.00%
Common Units | Golar Partners | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Common Units | Keppel Shipyard Limited (“Keppel”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	5.00%
Common Units | Black and Veatch (“B&V”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	0.40%
Series A Special Units | Keppel Shipyard Limited (“Keppel”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	10.00%
Series A Special Units | Black and Veatch (“B&V”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	0.90%
Series A Special Units | Golar | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	89.10%
Series B Special Units | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Entitlement to distributions		95.00%
Series B Special Units | Keppel Shipyard Limited (“Keppel”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	10.00%
Series B Special Units | Black and Veatch (“B&V”) | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	0.90%
Series B Special Units | Golar | Golar Hilli LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	89.10%
Share Capital | Golar Partners | Golar Hilli LLC | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Schedule of Equity Method Investments [Line Items]
Number of subsidiary shares sold in transaction | shares	1,096

DISPOSAL OF LONG-LIVED ASSETS_2

DISPOSAL OF LONG-LIVED ASSETS (Details) $ in Thousands	Jul. 06, 2016USD ($)vessel	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Schedule of Equity Method Investments [Line Items]
Net proceeds		$ 0	$ 0	$ 113,321
Net loss on loss of control of Golar Power		$ 0	$ 0	$ 8,483
Golar Power
Schedule of Equity Method Investments [Line Items]
Net proceeds	$ 113,000
Number of vessels disposed | vessel	2
Fair value of equity method investment	$ 232,701
Ownership percentage	50.00%	50.00%	50.00%
Net loss on loss of control of Golar Power	$ 8,483
Golar Power | Fair value of 50% retained investment in Golar Power
Schedule of Equity Method Investments [Line Items]
Fair value of equity method investment	$ 116,000
Ownership percentage	50.00%
Consideration received from Stonepeak	$ 116,000
Golar Power | Stonepeak
Schedule of Equity Method Investments [Line Items]
Ownership percentage disposed	50.00%

DISPOSAL OF LONG-LIVED ASSETS_3

DISPOSAL OF LONG-LIVED ASSETS - Calculation of loss on loss of control of Golar Power (Details) - USD ($) $ in Thousands	Jul. 06, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Net proceeds		$ 0	$ 0	$ 113,321
Less:
Loss on loss of control of Golar Power		$ 0	$ 0	$ (8,483)
Golar Power
Schedule of Equity Method Investments [Line Items]
Net proceeds	$ 113,000
Fair value of equity method investment	$ 232,701
Ownership percentage	50.00%	50.00%	50.00%
Less:
Carrying value of Golar Power’s net assets	$ 236,713
Guarantees issued by Golar to Golar Power	4,471
Loss on loss of control of Golar Power	(8,483)
Fair value of 50% retained investment in Golar Power | Golar Power
Schedule of Equity Method Investments [Line Items]
Fair value of equity method investment	$ 116,000
Ownership percentage	50.00%
Fair value of counter guarantees from Golar Power | Golar Power
Schedule of Equity Method Investments [Line Items]
Fair value of equity method investment	$ 3,701

DISPOSAL OF LONG-LIVED ASSETS_4

DISPOSAL OF LONG-LIVED ASSETS - Consideration Received for the Disposal (Details) - USD ($) $ in Thousands	Jul. 06, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Net proceeds		$ 0	$ 0	$ 113,321
Golar Power
Schedule of Equity Method Investments [Line Items]
Less: Fee paid in relation to the transaction	$ (3,000)
Net proceeds	$ 113,000
Stonepeak | Golar Power
Schedule of Equity Method Investments [Line Items]
Ownership percentage disposed	50.00%
Fair value of 50% retained investment in Golar Power | Golar Power
Schedule of Equity Method Investments [Line Items]
Consideration received from Stonepeak	$ 116,000

DISPOSAL OF LONG-LIVED ASSETS_5

DISPOSAL OF LONG-LIVED ASSETS - Underlying Carrying Value of Golar Powers' Net Assets at Deconsolidation Date (Details) - Golar Power $ in Thousands	Jul. 06, 2016USD ($)
Current
Cash and cash equivalents	$ 10,992
Restricted cash	15,463
Trade accounts receivable	1,474
Other receivables, prepaid expenses and accrued income	178
Short term amounts due from related parties	3,000
Inventory	952
Total current assets	32,059
Non-current
Newbuildings	50,436
Vessels, net	387,261
Total assets	469,756
Current
Current portion of long-term debt	20,032
Trade accounts payable	969
Accrued expenses	21,357
Total current liabilities	42,358
Non-current
Long-term debt	190,685
Total liabilities	233,043
Equity
Stockholders’ equity	236,713
Total liabilities and stockholders' equity	$ 469,756

DISPOSAL OF LONG-LIVED ASSETS_6

DISPOSAL OF LONG-LIVED ASSETS - Guarantees (Details) - Golar Power $ in Thousands	Jul. 06, 2016USD ($)
Schedule of Equity Method Investments [Line Items]
Guarantees issued	$ 4,471
Debt guarantees
Schedule of Equity Method Investments [Line Items]
Guarantees issued	3,283
Shipyard guarantee
Schedule of Equity Method Investments [Line Items]
Guarantees issued	$ 1,188

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)segment	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Jul. 06, 2016
Segment Reporting [Abstract]
Number of reportable segments | segment	3
Segmental information:
Depreciation and amortization	$ 93,689	$ 76,522	$ 72,972
Total operating revenues	430,604	143,537	80,257
Depreciation and amortization	(93,415)	(76,522)
Other operating expenses	(275,918)	(167,572)	(148,392)
Other operating gains and losses	53,489	15,100	16
Operating income (loss)	114,486	(85,457)	(141,091)
Operating income (loss)	114,486	(85,457)	(141,091)
Equity in net (losses) earnings of affiliates	(157,636)	(25,448)	47,878
Total assets	4,806,595	4,764,287	4,256,911
Investment in affiliates	571,782	703,225	648,780
Capital expenditures	$ 139,693	$ 391,901	234,518
Golar Power
Segmental information:
Ownership percentage	50.00%	50.00%		50.00%
Investment in affiliates	$ 266,151	$ 228,696
Intersegment Eliminations
Segmental information:
Depreciation and amortization	0	0	0
Total operating revenues	0	0	0
Other operating expenses	0	0	0
Other operating gains and losses	0	0	0
Operating income (loss)	0	0	0
Operating income (loss)	(335)	(4,568)	(275)
Equity in net (losses) earnings of affiliates	0	0	0
Total assets	(5,451)	(5,116)	(548)
Investment in affiliates	0	0	0
Capital expenditures	0	0	0
Vessel Operations | Operating Segments
Segmental information:
Depreciation and amortization	65,496	76,522	72,972
Total operating revenues	302,979	143,537	80,257
Other operating expenses	(231,887)	(163,207)	(144,816)
Other operating gains and losses	50,740	0	16
Operating income (loss)	56,336	(96,192)	(137,515)
Operating income (loss)	56,671	(91,624)	(137,240)
Equity in net (losses) earnings of affiliates	(138,676)	1,503	37,344
Total assets	2,990,506	3,025,244	3,152,311
Investment in affiliates	305,631	472,482	512,046
Capital expenditures	22,978	1,349	33,698
Vessel Operations | Intersegment Eliminations
Segmental information:
Operating income (loss)	335	4,568	275
Vessels - FLNG | Operating Segments
Segmental information:
Depreciation and amortization	28,193	0	0
Total operating revenues	127,625	0	0
Other operating expenses	(44,031)	(4,365)	(3,576)
Other operating gains and losses	2,749	15,100	0
Operating income (loss)	58,150	10,735	(3,576)
Operating income (loss)	58,150	10,735	(3,576)
Equity in net (losses) earnings of affiliates	(2,047)	(8,153)	0
Total assets	1,555,389	1,515,463	978,614
Investment in affiliates	0	2,047	10,200
Capital expenditures	116,715	390,552	200,820
Vessels - FLNG | Intersegment Eliminations
Segmental information:
Operating income (loss)	0	0	0
Golar Power | Operating Segments
Segmental information:
Depreciation and amortization	0	0	0
Total operating revenues	0	0	0
Other operating expenses	0	0	0
Other operating gains and losses	0	0	0
Operating income (loss)	0	0	0
Operating income (loss)	0	0	0
Equity in net (losses) earnings of affiliates	(16,913)	(18,798)	10,534
Total assets	266,151	228,696	126,534
Investment in affiliates	266,151	228,696	126,534
Capital expenditures	0	0	0
Golar Power | Intersegment Eliminations
Segmental information:
Operating income (loss)	$ 0	$ 0	$ 0

SEGMENT INFORMATION - Revenues

SEGMENT INFORMATION - Revenues from External Customers (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting [Abstract]
Benchmark percentage of revenue for major customer	10.00%	10.00%	10.00%
Collaborative Arrangement
Revenues from external customers:
Time and voyage charter revenues	$ 73,931	$ 28,327	$ 13,730
The Cool Pool | Sales Revenue, net | Customer Concentration Risk
Revenues from external customers:
Concentration risk amount	$ 251,070	$ 106,302	$ 51,075
Concentration risk percentage	62.00%	91.00%	77.00%
Time and voyage charter revenues	$ 251,100
The Cool Pool | Sales Revenue, net | Customer Concentration Risk | Collaborative Arrangement
Revenues from external customers:
Time and voyage charter revenues	73,900
The Cool Pool | Sales Revenue, net | Customer Concentration Risk | Non-collaborative Arrangement Transactions
Revenues from external customers:
Time and voyage charter revenues	177,200
Perenco and SNH | Sales Revenue, net | Customer Concentration Risk
Revenues from external customers:
Concentration risk amount	$ 127,625	$ 0	$ 0
Concentration risk percentage	31.00%	0.00%	0.00%
An energy and logistics company | Sales Revenue, net | Customer Concentration Risk
Revenues from external customers:
Concentration risk amount	$ 9,235	$ 9,235	$ 7,975
Concentration risk percentage	2.00%	8.00%	12.00%

SEGMENT INFORMATION - Geographi

SEGMENT INFORMATION - Geographic Data (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues from External Customers and Long-Lived Assets [Line Items]
Total operating revenues	$ 430,604	$ 143,537	$ 80,257
Assets	4,806,595	4,764,287	4,256,911
Liquefaction Services
Revenues from External Customers and Long-Lived Assets [Line Items]
Total operating revenues	127,625	0	0
Liquefaction Services | Vessels - FLNG | CAMEROON
Revenues from External Customers and Long-Lived Assets [Line Items]
Total operating revenues	127,625	0	0
Assets	$ 1,535,389	$ 1,515,463	$ 0

REVENUE - Change in Contract Ba

REVENUE - Change in Contract Balances (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)
Change in Contract with Customer, Asset [Abstract]
Contract with customer, asset, net, beginning balance	$ 17,245
Payments received for services billed	(14,558)
Services provided and billed in current period	143,670
Payments received for services billed in current period	(120,975)
Impairment	(1,006)
Contract with customer, asset, net, ending balance	24,376
Change in Contract with Customer, Liability [Abstract]
Contract with customer, liability, beginning balance	0
Services provided and billed in current period	33,763
Deferred commissioning period billing	(2,467)
Contract with customer, liability, ending balance	$ 31,296

REVENUE - Management Fee Revenu

REVENUE - Management Fee Revenue (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amounts due from related parties	$ 9,425	$ 7,898
Amounts due to related parties	5,417	8,734
Golar Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Amounts due from related parties	3,100	7,200
Amounts due to related parties	$ 4,300	$ 10,000

REVENUE - Liquefaction services

REVENUE - Liquefaction services revenue (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)$ / barrel	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	$ 430,604	$ 143,537	$ 80,257
Amortization of Day 1 gain	$ (38,610)	24,498	26,644
Oil price per barrel | $ / barrel	60
Contract with customer, liability, revenue recognized	$ 33,763
Derivative asset	95,500	112,317
Base tolling fee
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	119,677	0
Liquefaction Services
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	127,625	0	$ 0
Amortization of deferred commissioning period billing	2,467	0
Amortization of Day 1 gain	5,817	0
Other	$ (336)	0
Vessels - FLNG
Disaggregation of Revenue [Line Items]
Derivative asset		$ 79,600

IMPAIRMENT OF NON-CURRENT ASS_3

IMPAIRMENT OF NON-CURRENT ASSETS (Details)	12 Months Ended
	Dec. 31, 2018USD ($)vessel	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Impairment of long-term assets:
Number of vessels | vessel	9
Impairment charge	$ 0	$ 0	$ 1,706,000
Vessels, Net	3,271,379,000	$ 2,077,059,000
Equity method investment, other than temporary impairment	149,400,000
Golar Arctic
Impairment of long-term assets:
Impairment charge	0
Market value	76,750,000
Vessels, Net	134,400,000
Deficit	57,650,000
Golar Seal
Impairment of long-term assets:
Market value	178,750,000
Vessels, Net	179,000,000
Deficit	250,000
Golar Bear
Impairment of long-term assets:
Market value	182,000,000
Vessels, Net	183,900,000
Deficit	1,900,000
Golar Frost
Impairment of long-term assets:
Market value	182,000,000
Vessels, Net	187,700,000
Deficit	5,700,000
Golar Viking
Impairment of long-term assets:
Market value	78,250,000
Vessels, Net	112,300,000
Deficit	34,050,000
Golar Glacier
Impairment of long-term assets:
Market value	182,500,000
Vessels, Net	183,500,000
Deficit	1,000,000
Golar Snow
Impairment of long-term assets:
Market value	184,500,000
Vessels, Net	191,800,000
Deficit	7,300,000
Golar Ice
Impairment of long-term assets:
Market value	184,000,000
Vessels, Net	192,000,000
Deficit	8,000,000
Golar Kelvin
Impairment of long-term assets:
Market value	183,500,000
Vessels, Net	185,600,000
Deficit	$ 2,100,000

(LOSSES) GAINS ON DERIVATIVE _3

(LOSSES) GAINS ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Other financial items, net:
(Losses) gains on derivative instruments	$ (30,541)	$ 20,696	$ 16,491
Impairment of loan	0	0	(7,627)
Financing arrangement fees and other costs	(244)	(677)	(404)
Amortization of debt guarantee	861	1,548	1,563
Foreign exchange loss on operations	(1,997)	(888)	(1,909)
Other	(101)	(52)	577
Other Financial Items	(1,481)	(69)	(7,800)
Interest rate swap
Other financial items, net:
(Losses) gains on derivative instruments	604	6,614	2,818
Interest income (expense) on undesignated interest rate swaps (see note 27)	8,069	(3,802)	(10,153)
Equity Contract
Other financial items, net:
(Losses) gains on derivative instruments	(30,663)	16,622	24,819
Currency swap
Other financial items, net:
(Losses) gains on derivative instruments	(1,151)	821	(993)
Earn-Out Units
Other financial items, net:
(Losses) gains on derivative instruments	$ (7,400)	$ 441	$ 0

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Components of income tax expense:
Current tax expense	$ 836	$ 1,478	$ 1,035
Deferred tax expense	431	27	90
Amortization of tax benefit arising on intra-group transfers of non-current assets	0	0	(1,714)
Total income tax expense (benefit)	$ 1,267	$ 1,505	$ (589)
Statutory tax rate	0.00%	0.00%	0.00%

INCOME TAXES - Tax Expense (Ben

INCOME TAXES - Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income taxes at statutory rate	$ 0	$ 0	$ 0
Effect of deferred tax benefit on intra-group transfers of non-current assets	0	0	(1,714)
Effect of movement in deferred tax balances	431	27	90
Effect of adjustments in respect of current tax in prior periods	(369)	(5)	(334)
Effect of taxable income in various countries	1,205	1,483	1,369
Total income tax expense (benefit)	$ 1,267	$ 1,505	$ (589)

LOSS PER SHARE (Details)

LOSS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Components of the numerator for the calculation of basic and diluted EPS:
Net loss attributable to Golar LNG Ltd stockholders - basic and diluted	$ (231,428)	$ (179,703)	$ (186,531)
Components of the denominator for the calculation of basic and diluted EPS:
Weighted average number of common shares outstanding	100,684	100,597	93,933
Earnings per share, basic and diluted:
Basic and diluted (in dollars per share)	$ (2.30)	$ (1.79)	$ (1.99)

OPERATING LEASES (Details)

OPERATING LEASES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Future minimum payments under non-cancellable operating leases:
2019	$ 5,417
2020	3,756
2021	2,682
2022	2,425
2023	6,180
Total minimum lease payments	20,460
Total rental expense for operating leases	8,200	$ 19,300	$ 29,600
Minimum rentals	6,100
Contingent rentals	2,200
Sublease rentals	100
Vessels leased to third parties
Minimum contractual future revenues to be received:
Cost	331,500	191,100
Accumulated depreciation	35,600	$ 53,600
Time charters
Minimum contractual future revenues to be received:
2019	25,851
Total	$ 25,851

RESTRICTED CASH AND SHORT-TER_3

RESTRICTED CASH AND SHORT-TERM DEPOSITS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2017	Dec. 19, 2017	Nov. 30, 2015	Jul. 31, 2013
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	$ 486,426,000		$ 397,815,000
Less: Amounts included in current restricted cash and short-term deposits	(332,033,000)		(222,265,000)
Long-term restricted cash	154,393,000		175,550,000
Minimum consolidated cash balances	50,000,000
Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Letter of credit available to project partner				$ 300,000,000	$ 400,000,000
Equity Swap
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	82,863,000		58,351,000
Bank Guarantee
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	691,000		99,000
Bank Guarantee | Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	174,597,000		174,737,000	$ 57,200,000	$ 305,000,000
Variable Interest Entity, Primary Beneficiary
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	176,428,000		130,063,000
Line of Credit
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	17,657,000		33,752,000
Line of Credit | Margin Loan Facility
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	33,413,000		0
Office Lease
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	777,000		$ 813,000
Share Repurchase Forward Swap
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits	$ 82,900,000
Collateral required under share repurchase agreement, percentage of total purchase price	20.00%
Secured Debt | Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Maximum borrowing capacity	$ 700,000,000
Secured Debt | Line of Credit | $1.125 billion newbuild facility
Restricted Cash and Cash Equivalents Items [Line Items]
Maximum borrowing capacity	$ 1,125,000,000					$ 1,125,000,000
Scenario, Forecast | Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Letter of credit available to project partner		$ 250,000,000

OTHER CURRENT ASSETS (Details)

OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Other Assets [Abstract]
Prepaid expenses	$ 4,285	$ 3,045
Other receivables	14,435	3,002
Prepaid expenses and other assets	$ 18,720	$ 6,047

INVESTMENTS IN AFFILIATES - Own

INVESTMENTS IN AFFILIATES - Ownership Percentage (Details)	Dec. 31, 2018	Dec. 31, 2017	Jul. 06, 2016
Schedule of Equity Method Investments [Line Items]
Investments, ownership percentage	100.00%
Golar Partners
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	32.00%	31.80%
Investments, ownership percentage	32.00%	31.80%
Percentage of IDRs	100.00%
Egyptian Company for Gas Services S.A.E (ECGS)
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	50.00%	50.00%
Golar Power
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	50.00%	50.00%	50.00%
OneLNG
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	51.00%	51.00%
The Cool Pool Limited (Pool Manager)
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	50.00%	33.00%
Avenir LNG Ltd
Schedule of Equity Method Investments [Line Items]
Ownership percentage, equity method investment	22.50%	0.00%
Partnership Interest | Golar Partners
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners	2.00%

INVESTMENTS IN AFFILIATES - Car

INVESTMENTS IN AFFILIATES - Carrying Amount (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	$ 571,782	$ 703,225	$ 648,780
Golar Partners
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	271,160	467,097
Golar Power
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	266,151	228,696
OneLNG
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	0	2,047
Avenir
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	28,710	0
Other
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	5,761	5,385
ECGS
Schedule of Equity Method Investments [Line Items]
Investments in affiliates	$ 5,300	$ 5,400

INVESTMENTS IN AFFILIATES - Com

INVESTMENTS IN AFFILIATES - Components (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Cost	$ 981,196	$ 877,810
Dividends	(336,286)	(287,263)
Equity in net earnings of affiliates	95,458	107,553
Impairment of investment in affiliate	(149,389)	0
Share of other comprehensive income of affiliates	(19,197)	5,125
Equity in net assets of affiliates	$ 571,782	$ 703,225	$ 648,780

INVESTMENTS IN AFFILIATES - Nar

INVESTMENTS IN AFFILIATES - Narrative (Details) $ / shares in Units, $ in Thousands	Nov. 08, 2018$ / sharesshares	Oct. 24, 2018$ / shares	Oct. 01, 2018USD ($)$ / sharesshares	Nov. 15, 2017USD ($)shares	Oct. 13, 2016USD ($)$ / sharesshares	Oct. 12, 2016$ / shares	Jul. 25, 2016	Nov. 30, 2017shares	Dec. 31, 2018USD ($)vessel$ / shares	Dec. 31, 2017USD ($)$ / shares	Dec. 31, 2016USD ($)	Jul. 06, 2016	Dec. 31, 2011USD ($)	Mar. 31, 2006$ / sharesshares
Equity method investments acquired:
Equity method investment, other than temporary impairment									$ 149,400
Minimum quarterly distribution per unit (in dollars per share) | $ / shares		$ 0.4042			$ 0.5775	$ 0.3850
Dividends received									15,837	$ 27,553	$ 26,515
Derivative asset									$ 95,500	112,317
Percentage of voting interest acquired									50.00%
Interest costs capitalized									$ 148,100
Investment in affiliates									$ 571,782	$ 703,225	648,780
Number of vessels | vessel									16
Number of vessels contributed | vessel									8
Investments, ownership percentage									100.00%
Common shares, par value (in dollars per share) | $ / shares									$ 1	$ 1
Egyptian Company for Gas Services S.A.E
Equity method investments acquired:
Common stock purchased (in shares) | shares														500,000
Common stock purchased, price per share (in dollars per share) | $ / shares														$ 1
Percentage of voting interest acquired									50.00%					50.00%
Investee capital share amount called													$ 7,500
Cash paid to maintain equity interest													$ 3,750
Ownership percentage, equity method investment													50.00%
Proceeds from dividends									$ 200	$ 0
Golar Partners
Equity method investments acquired:
Dividends received				$ 900					$ 48,400	$ 52,300	$ 54,700
Avenir LNG Ltd
Equity method investments acquired:
Ownership percentage, equity method investment									22.50%	0.00%
Ownership percentage after transaction	22.50%
Investment in affiliates									$ 28,710	$ 0
Goodwill									$ 3,800
Avenir LNG Ltd | Stolt-Nielsen Ltd and Höegh LNG Holdings Ltd
Equity method investments acquired:
Investment company, committed capital			$ 182,000
Avenir LNG Ltd | Stolt-Nielsen Limited
Equity method investments acquired:
Ownership percentage after transaction	45.00%
Avenir LNG Ltd | Hoegh LNG Holdings Limited
Equity method investments acquired:
Ownership percentage after transaction	22.50%
Golar Partners
Equity method investments acquired:
Ownership percentage, equity method investment									32.00%	31.80%
Investment in affiliates									$ 271,160	$ 467,097
Percentage of IDRs									100.00%
Investments, ownership percentage									32.00%	31.80%
Golar Partners, Common Unit
Equity method investments acquired:
Number of units (in shares) | shares				374,295	2,994,364
Number of earn-out units (in shares) | shares					748,592			374,295
Golar Partners, General Partner Units
Equity method investments acquired:
Number of units (in shares) | shares				7,639	61,109
Number of earn-out units (in shares) | shares					15,278			7,639
OneLNG
Equity method investments acquired:
Ownership percentage, equity method investment									51.00%	51.00%
Ownership percentage after transaction							51.00%
Investment in affiliates									$ 0	$ 2,047
OneLNG | Schlumberger
Equity method investments acquired:
Ownership percentage after transaction							49.00%
The Cool Pool Limited (Pool Manager)
Equity method investments acquired:
Ownership percentage, equity method investment									50.00%	33.00%
GasLog
Equity method investments acquired:
Number of vessels contributed | vessel									6
Golar Power
Equity method investments acquired:
Ownership percentage, equity method investment									50.00%	50.00%		50.00%
Related party transaction amount									$ 55,000
Interest costs capitalized									10,500	$ 6,600
Investment in affiliates									$ 266,151	228,696
Number of vessels contributed | vessel									2
Equity Method Investments
Equity method investments acquired:
Reclassification of derivative					$ (15,000)
Other Noncurrent Assets
Equity method investments acquired:
Reclassification of derivative					$ 15,000
Earn-Out Units
Equity method investments acquired:
Derivative liability										7,400
Loss on derivative									$ 7,400
Derivative asset									$ 0	$ 7,400
Private Placement | Avenir LNG Ltd
Equity method investments acquired:
Investment in affiliates			$ 24,800
Number of subsidiary shares sold in transaction | shares	11,000,000		99,000,000
Shares subscribed but unissued | shares			24,800,000
Common shares, par value (in dollars per share) | $ / shares			$ 1
Sale of stock, price per share | $ / shares	$ 1		$ 1
Avenir LNG Ltd
Equity method investments acquired:
Ownership percentage, equity method investment			25.00%
Avenir LNG Ltd | Stolt-Nielsen Ltd and Höegh LNG Holdings Ltd
Equity method investments acquired:
Investment company, committed capital			$ 182,000

INVESTMENTS IN AFFILIATES - Sum

INVESTMENTS IN AFFILIATES - Summarized Financial Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
ECGS
Balance Sheet
Current assets	$ 22,955	$ 37,476
Non-current assets	244	333
Current liabilities	11,510	25,836
Non-current liabilities	1,203	1,203
Non-controlling interests	0	0
Statement of Operations
Revenue	30,596	44,052
Net (loss) income	207	1,047
Golar Partners
Balance Sheet
Current assets	164,529	311,496
Non-current assets	2,076,288	2,115,875
Current liabilities	323,508	180,087
Non-current liabilities	1,157,792	1,399,683
Non-controlling interests	79,902	76,544
Statement of Operations
Revenue	346,650	433,102
Net (loss) income	76,548	144,848
The Cool Pool Limited (Pool Manager)
Balance Sheet
Current assets	98,448	40,661
Non-current assets	0	0
Current liabilities	98,448	40,661
Non-current liabilities	0	0
Non-controlling interests	0	0
Statement of Operations
Revenue	346,170	159,460
Net (loss) income	0	0
Golar Power
Balance Sheet
Current assets	79,029	61,374
Non-current assets	955,100	713,646
Current liabilities	285,447	60,033
Non-current liabilities	149,114	174,656
Non-controlling interests	1,541	0
Statement of Operations
Revenue	78,732	7,354
Net (loss) income	(10,202)	(7,899)
OneLNG
Balance Sheet
Current assets	4,884	14,955
Non-current assets	0	0
Current liabilities	8,741	10,941
Non-current liabilities	0	0
Non-controlling interests	0	0
Statement of Operations
Revenue	7	0
Net (loss) income	(6,646)	$ (14,883)
Avenir LNG Ltd
Balance Sheet
Current assets	78,591
Non-current assets	20,840
Current liabilities	1,760
Non-current liabilities	0
Statement of Operations
Revenue	487
Net (loss) income	$ (975)

ASSET UNDER DEVELOPMENT (Detail

ASSET UNDER DEVELOPMENT (Details) - USD ($) $ in Thousands	1 Months Ended
	Feb. 28, 2019	Dec. 31, 2018	Dec. 31, 2017
Capitalized Costs, Oil and Gas Producing Activities, Net [Abstract]
Asset under development		$ 20,000	$ 1,177,489
Gimi Conversion
Capitalized Costs, Oil and Gas Producing Activities, Net [Abstract]
Purchase price installments		0	962,709
Interest costs capitalized		0	116,416
Other costs capitalized		20,000	98,364
Asset under development		$ 20,000	$ 1,177,489
Subsequent Event | Gimi Conversion
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Term of charter	20 years

VESSELS AND EQUIPMENT, NET (Det

VESSELS AND EQUIPMENT, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Cost
As of January 1	$ 2,431,136	$ 2,438,720
Additions	11,304	1,349
Transfer from asset under development	1,296,431	0
Transfer to asset under development	(90,828)	0
Write-offs	(9,995)	(8,933)
As of December 31	3,638,048	2,431,136	$ 2,438,720
Depreciation, amortization and impairment
As of January 1	(354,077)	(284,889)
Charge for the year	(93,415)	(76,522)
Transfer to asset under development	70,828	0
Write-offs	9,995	7,334
As of December 31	(366,669)	(354,077)	(284,889)
Net book value as at December 31	3,271,379	2,077,059
Interest costs capitalized	148,100
Vessels and equipment
Depreciation, amortization and impairment
Charge for the year	(93,400)	(76,500)	$ (73,000)
Drydocking
Cost
As of January 1	37,400
As of December 31	133,300	37,400
Depreciation, amortization and impairment
As of January 1	(24,300)
As of December 31	(26,000)	(24,300)
Office equipment
Cost
As of January 1	3,900
As of December 31	5,700	$ 3,900
License
Depreciation, amortization and impairment
Amortization charge	$ 300

VESSELS AND EQUIPMENT, NET - Na

VESSELS AND EQUIPMENT, NET - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Property and equipment:
Vessels and equipment	$ 3,638,048	$ 2,431,136	$ 2,438,720
Accumulated amortization	366,669	354,077	284,889
Depreciation and amortization expense	93,415	76,522
Drydocking
Property and equipment:
Vessels and equipment	133,300	37,400
Accumulated amortization	26,000	24,300
Vessels and equipment
Property and equipment:
Depreciation and amortization expense	93,400	76,500	$ 73,000
Vessels (excluding converted FSRUs and FLNG)
Property and equipment:
Amounts pledged as collateral	3,244,300	2,032,700
Office equipment
Property and equipment:
Vessels and equipment	$ 5,700	$ 3,900

OTHER NON-CURRENT ASSETS (Detai

OTHER NON-CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Components of other non-current assets:
Mark-to-market derivative valuation	$ 95,500	$ 112,317
Other long-term assets, including deferred tax asset (see note 11)	40,729	37,891
Other non-current assets	139,104	157,504
Golar Gimi
Components of other non-current assets:
Other long-term assets, including deferred tax asset (see note 11)	31,000	31,000
Energy Related Derivative
Components of other non-current assets:
Mark-to-market derivative valuation	84,730	94,700
Interest rate swap
Components of other non-current assets:
Mark-to-market derivative valuation	6,298	10,166
Other
Components of other non-current assets:
Mark-to-market derivative valuation	0	7,400
OLT Offshore LNG Toscana S.p.A (OLT–O)
Components of other non-current assets:
Investment in OLT Offshore LNG Toscana	$ 7,347	$ 7,347
Noncontrolling interest, ownership percentage by noncontrolling owners	2.70%

DEBT - Schedule of Long-Term De

DEBT - Schedule of Long-Term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Components of long-term debt:
Total long-term and short-term debt	$ 2,565,359	$ 2,410,847
Less: current portion of long-term debt and short-term debt	(730,257)	(1,384,933)
Long-term debt	1,835,102	1,025,914
Repayments of long-term debt:
2019	732,184
2020	245,643
2021	103,976
2022	457,637
2023	103,976
2024 and thereafter	938,780
Total debt (gross)	2,582,196	2,434,900
Deferred finance charges	(16,837)	(24,053)
Total debt	2,565,359	2,410,847
Secured Debt | FLNG Hilli facility
Repayments of long-term debt:
Total debt (gross)	0	$ 525,000
Variable Interest Entity, Primary Beneficiary
Repayments of long-term debt:
2019	646,959
2020	82,260
2021	82,260
2022	82,260
2023	82,260
2024 and thereafter	873,629
Total debt (gross)	1,849,628
Deferred finance charges	(2,343)
Total debt	1,847,285
Golar
Repayments of long-term debt:
2019	85,225
2020	163,383
2021	21,716
2022	375,377
2023	21,716
2024 and thereafter	65,151
Total debt (gross)	732,568
Deferred finance charges	(14,494)
Total debt	$ 718,074

DEBT - Schedule of Debt (Detail

DEBT - Schedule of Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total debt (gross)	$ 2,582,196	$ 2,434,900
Subtotal (excluding lessor VIE loans)	732,568	1,346,496
Deferred finance charges	(16,837)	(24,053)
Total debt	2,565,359	2,410,847
Secured Debt | Golar Arctic facility
Debt Instrument [Line Items]
Total debt (gross)	58,300	65,600
Secured Debt | Golar Viking facility
Debt Instrument [Line Items]
Total debt (gross)	46,875	52,083
Secured Debt | Margin Loan Facility
Debt Instrument [Line Items]
Total debt (gross)	100,000	119,125
Secured Debt | FLNG Hilli facility
Debt Instrument [Line Items]
Total debt (gross)	0	525,000
Secured Debt | Golar Bear Facility
Debt Instrument [Line Items]
Total debt (gross)	86,200	96,975
Secured Debt | Golar Frost Facility
Debt Instrument [Line Items]
Total debt (gross)	87,532	98,474
Secured Debt | Golar Glacier Facility
Debt Instrument [Line Items]
Total debt (gross)	154,226	161,876
Secured Debt | Golar Snow Facility
Debt Instrument [Line Items]
Total debt (gross)	154,566	162,566
Secured Debt | Golar Kelvin Facility
Debt Instrument [Line Items]
Total debt (gross)	182,540	182,540
Secured Debt | Golar Ice Facility
Debt Instrument [Line Items]
Total debt (gross)	117,888	134,954
Secured Debt | Golar Tundra Facility
Debt Instrument [Line Items]
Total debt (gross)	121,741	198,613
Secured Debt | Golar Seal CCBFL VIE Loan Facility
Debt Instrument [Line Items]
Total debt (gross)	123,524	143,849
Secured Debt | Golar Crystal Facility
Debt Instrument [Line Items]
Total debt (gross)	97,163	104,006
Secured Debt | Hilli Facility
Debt Instrument [Line Items]
Total debt (gross)	897,980	0
Convertible Debt | 2017 Convertible bonds
Debt Instrument [Line Items]
Total debt (gross)	353,661	340,173
Shareholder Notes Payable | Keppel Shareholder Loan
Debt Instrument [Line Items]
Total debt (gross)	0	44,066
Shareholder Notes Payable | B&V Shareholder Loan
Debt Instrument [Line Items]
Total debt (gross)	$ 0	$ 5,000

DEBT - Credit Facilities Narrat

DEBT - Credit Facilities Narrative (Details)	Aug. 30, 2018	Jun. 30, 2018USD ($)	Jun. 24, 2018USD ($)	Mar. 31, 2016	Jul. 31, 2013USD ($)newbuildtranche	Dec. 31, 2018USD ($)vessel	Apr. 30, 2018USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Secured Debt | Golar Crystal Facility
Debt Instrument [Line Items]
Face amount							$ 101,000,000
Maturity period of debt				10 years
Secured Debt | Hilli Lessor VIE
Debt Instrument [Line Items]
Face amount		$ 840,000,000
Maturity period of debt		10 years
Secured Debt | Golar Arctic facility
Debt Instrument [Line Items]
Maximum borrowing capacity									$ 87,500,000
Basis spread on variable rate						2.25%
Maturity term						5 years
Final payment amount						$ 52,800,000
Secured Debt | Golar Viking facility
Debt Instrument [Line Items]
Maximum borrowing capacity								$ 62,500,000
Basis spread on variable rate						2.50%
Maturity term						5 years
Final payment amount						$ 37,800,000
Secured Debt | FLNG Hilli facility
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 700,000,000
Percentage of initial project budget						60.00%
Interest rate						6.25%
Term of sale leaseback transaction	10 years
Secured Debt | $1.125 billion newbuild facility | Line of Credit
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 1,125,000,000	$ 1,125,000,000
Balance outstanding under pre-delivery facility						$ 173,700,000
Number of vessels					8	2
Description of variable rate basis						LIBOR
Number of tranches | tranche					3
Secured Debt | $449 million newbuild facility | Line of Credit
Debt Instrument [Line Items]
Maturity term						12 years
Percentage guaranteed						95.00%
Shareholder Notes Payable | K-Sure Tranche
Debt Instrument [Line Items]
Interest rate						2.10%
Shareholder Notes Payable | KEXIM Tranche
Debt Instrument [Line Items]
Interest rate						2.75%
Affiliated Entity | Secured Debt | Hilli Lessor VIE
Debt Instrument [Line Items]
Face amount		$ 120,000,000
Hilli / CSSC | Affiliated Entity | Secured Debt | FLNG Hilli facility
Debt Instrument [Line Items]
Repayments of related party debt			$ 640,000,000
Face amount			$ 960,000,000

DEBT - Convertible Bonds Narrat

DEBT - Convertible Bonds Narrative (Details)	Feb. 17, 2017USD ($)shares$ / shares	Feb. 13, 2017$ / shares	Sep. 30, 2018$ / shares	Jun. 30, 2018$ / shares	Dec. 31, 2018shares	Jul. 31, 2018USD ($)	Dec. 31, 2017shares	Mar. 03, 2017USD ($)shares	Mar. 31, 2012
Convertible Debt | Convertible Bonds
Debt Instrument [Line Items]
Coupon rate									3.75%
Convertible Debt | 2017 Convertible Bonds
Debt Instrument [Line Items]
Face amount	$ 402,500,000
Maturity period of debt	5 years
Coupon rate	2.75%
Debt instrument conversion ratio	0.0265308		0.0266375	0.0266102
Debt instrument conversion price (in dollars per share) | $ / shares	$ 37.69		$ 37.54	$ 37.58
Debt instrument threshold percentage of stock price trigger	35.00%
Share price (in dollars per share) | $ / shares		$ 27.92
Proceeds from issuance of convertible bonds	$ 360,200,000
Convertible debt	320,300,000
Convertible, carrying amount of equity component	39,900,000
Distribution (in dollars per share) | $ / shares			$ 0.15	$ 0.125
Derivative, cost of hedge	$ 31,200,000
Number of shares issued if converted | shares	10,678,647
Debt instrument capped call strike price (in usd per share) | $ / shares	$ 37.69
Cap price premium | $ / shares	$ 48.86
Capped price threshold		75.00%
Debt instrument all-in cost percent	4.30%
Secured Debt | Margin Loan Facility
Debt Instrument [Line Items]
Maturity period of debt					3 years
Proceeds of new margin loan facility (up to)								$ 150,000,000
Common units, pledged as collateral | shares					21,226,586		20,852,291	20,852,291
Facility remaining until maturity						$ 100,000,000
LIBOR | Secured Debt | Margin Loan Facility
Debt Instrument [Line Items]
Basis spread on variable rate					3.95%

DEBT - Shareholder Loans Narrat

DEBT - Shareholder Loans Narrative (Details) - USD ($) $ in Thousands	1 Months Ended
	Nov. 30, 2014	Sep. 30, 2014	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Long-term debt			$ 2,565,359	$ 2,410,847
Other current liabilities			$ 121,529	62,282
KSI Shareholder Loan
Debt Instrument [Line Items]
Balloon payment, period after final acceptance date		120 months
Black and Veatch Shareholder Loan
Debt Instrument [Line Items]
Balloon payment, period after final acceptance date	120 months
Shareholder Notes Payable | KSI Shareholder Loan
Debt Instrument [Line Items]
Long-term debt				$ 44,100
Interest rate				6.00%
Periodic payment, percentage of value of loan		2.50%
Frequency of periodic payments		6 months
Periodic payment commencement, period after final acceptance date		12 months
Shareholder Notes Payable | September 2014 - KSI Shareholder Loan
Debt Instrument [Line Items]
Long-term debt				$ 21,700
Shareholder Notes Payable | November 2014 - KSI Shareholder Loan
Debt Instrument [Line Items]
Long-term debt				$ 9,000
Shareholder Notes Payable | Black and Veatch Shareholder Loan
Debt Instrument [Line Items]
Long-term debt	$ 5,000
Interest rate	6.00%
Periodic payment, percentage of value of loan	2.50%
Frequency of periodic payments	6 months
Periodic payment commencement, period after final acceptance date	12 months
Golar GHK Lessors Limited | Keppel Shipyard Limited
Debt Instrument [Line Items]
Percentage ownership of subsidiary sold		10.00%
Consideration received on sale of subsidiary ownership interest		$ 21,700
Golar GHK Lessors Limited | Black and Veatch
Debt Instrument [Line Items]
Consideration received on sale of subsidiary ownership interest	$ 5,000
Number of subsidiary shares sold in transaction	0.01

DEBT - Schedule of Tranches (De

DEBT - Schedule of Tranches (Details) - Line of Credit - Secured Debt	12 Months Ended
	Dec. 31, 2018	Jul. 31, 2013
$449 million newbuild facility
Debt Instrument [Line Items]
Proportion of facility		40.00%
Term of loan from date of drawdown	12 years
Repayment terms	Six-monthly installments
$450 million newbuild facility
Debt Instrument [Line Items]
Proportion of facility		40.00%
Term of loan from date of drawdown	12 years
Repayment terms	Six-monthly installments
$226 million newbuild facility
Debt Instrument [Line Items]
Proportion of facility		20.00%
Term of loan from date of drawdown	5 years
Repayment terms	Six-monthly installments, unpaid balance to be refinanced after 5 years

DEBT - ICBCL VIE Loans Narrativ

DEBT - ICBCL VIE Loans Narrative (Details) - USD ($)	1 Months Ended
	Jun. 30, 2015	Jan. 31, 2015	Oct. 31, 2014	Dec. 31, 2018	Dec. 31, 2017	Feb. 28, 2015
Debt Instrument [Line Items]
Total debt				$ 2,582,196,000	$ 2,434,900,000
Golar Glacier Facility | Secured Debt
Debt Instrument [Line Items]
Total debt				154,226,000	161,876,000
Golar Snow Facility | Secured Debt
Debt Instrument [Line Items]
Total debt				154,566,000	162,566,000
Golar Kelvin Facility | Secured Debt
Debt Instrument [Line Items]
Total debt				182,540,000	182,540,000
Golar Ice Facility | Secured Debt
Debt Instrument [Line Items]
Total debt				117,888,000	$ 134,954,000
Variable Interest Entity, Primary Beneficiary
Debt Instrument [Line Items]
Total debt				$ 1,849,628,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1401 Limited
Debt Instrument [Line Items]
Maturity period of debt			10 years
Maturity period of debt			10 years
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1401 Limited | Golar Glacier Facility | Secured Debt
Debt Instrument [Line Items]
Total debt			$ 184,800,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1401 Limited | Golar Glacier Facility | Glacier Senior Facility | Secured Debt
Debt Instrument [Line Items]
Total debt			153,000,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1401 Limited | Golar Glacier Facility | Golar Glacier Junior Facility | Secured Debt
Debt Instrument [Line Items]
Total debt			$ 31,800,000
Interest rate			6.00%
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1402 Limited | Golar Snow Facility
Debt Instrument [Line Items]
Face amount		$ 182,600,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1402 Limited | Golar Snow Facility | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest rate		6.00%
Face amount		$ 22,600,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1402 Limited | Golar Snow Facility | Senior Notes
Debt Instrument [Line Items]
Maturity period of debt		10 years
Face amount		$ 160,000,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1405 Limited | Golar Kelvin Facility | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest rate		6.00%
Face amount		$ 182,500,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1405 Limited | Golar Kelvin Facility | Senior Notes
Debt Instrument [Line Items]
Maturity period of debt	10 years
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1406 Limited | Golar Ice Facility | Junior Subordinated Debt
Debt Instrument [Line Items]
Interest rate						2.78%
Face amount						$ 172,000,000
Variable Interest Entity, Primary Beneficiary | Hai Jiao 1406 Limited | Golar Ice Facility | Senior Notes
Debt Instrument [Line Items]
Maturity period of debt	10 years

DEBT - CCBFL VIE Loans Narrativ

DEBT - CCBFL VIE Loans Narrative (Details) - Secured Debt - USD ($)	1 Months Ended
	Mar. 31, 2016	Apr. 30, 2018
Golar Seal CCBFL VIE Loan Facility
Debt Instrument [Line Items]
Face amount	$ 162,400,000
Maturity period of debt	10 years
Interest rate	3.50%
Golar Crystal Facility
Debt Instrument [Line Items]
Face amount		$ 101,000,000
Maturity period of debt	10 years

DEBT - Debt Restrictions Narrat

DEBT - Debt Restrictions Narrative (Details) $ in Millions	Dec. 31, 2018USD ($)
Debt Disclosure [Abstract]
Restrictive covenants, minimum amount of cash and cash equivalents	$ 50

ACCRUED EXPENSES - COMPONENTS O

ACCRUED EXPENSES - COMPONENTS OF ACCRUED EXPENSES (Details) - USD ($) $ in Thousands		Dec. 31, 2018	Dec. 31, 2017
Payables and Accruals [Abstract]
Vessel operating and drydocking expenses		$ 24,041	$ 10,978
Administrative expenses		11,042	9,572
Interest expense		97,688	84,249
Current tax payable		463	1,096
Accrued expenses	[1]	$ 133,234	$ 105,895
[1]	This includes amounts arising from transactions with related parties (see note 28).

OTHER CURRENT LIABILITIES (Deta

OTHER CURRENT LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Mark-to-market swaps valuation:
Deferred operating cost and charterhire revenue	$ 8,206	$ 1,044
Dividends payable	16,762	5,032
Other	14,485	8,379
Other current liabilities	121,529	62,282
Currency swap
Mark-to-market swaps valuation:
Mark-to-market swaps valuation	1,322	223
Equity swap
Mark-to-market swaps valuation:
Mark-to-market swaps valuation	70,804	40,141
Energy Related Derivative
Mark-to-market swaps valuation:
Day 1 gain deferred revenue	$ 9,950	$ 7,463

OTHER NON-CURRENT LIABILITIES_2

OTHER NON-CURRENT LIABILITIES (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 03, 2017
Schedule of Other Long-Term Liabilities [Line Items]
Day 1 gain deferred revenue	$ 63,834	$ 72,138
Deferred commissioning period revenue	27,076	0
Pension obligations	32,972	37,537
Guarantees issued to Golar Partners	14,770	11,429
Other	6,912	11,444
Other long-term liabilities	145,564	132,548
Derivative liability	72,126	40,364
Deferred Commissioning Period Revenue	33,800
Asset retirement obligation	4,400	$ 9,800
Asset retirement obligation, period increase (decrease)	5,400
Asset retirement obligation, revision of estimate	5,600
Asset retirement obligation, accretion expense	200
Removal costs capitalized	4,400
Energy Related Derivative
Schedule of Other Long-Term Liabilities [Line Items]
Day 1 gain deferred revenue	$ 63,800
Derivative liability			$ 79,600

PENSIONS (Details)

PENSIONS (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2018USD ($)Defined_Benefit_Plan	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Defined contribution scheme:
Defined contribution scheme, charge to net income	$ 1,900	$ 1,700	$ 1,300
Pensions
Defined benefit schemes:
Number of defined benefit schemes | Defined_Benefit_Plan	2
Net actuarial loss (see note 26)	$ 9,218	12,799
Other comprehensive income, tax on actuarial loss	$ (400)	$ (300)	$ 0

PENSIONS - Net Periodic Benefit

PENSIONS - Net Periodic Benefit Costs (Details) - Pensions - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Components of net periodic benefit cost:
Service cost	$ 250	$ 313	$ 302
Interest cost	1,687	1,901	2,051
Expected return on plan assets	(926)	(843)	(806)
Recognized actuarial loss	1,392	1,182	1,060
Net periodic benefit cost	2,403	2,553	$ 2,607
Estimated net loss for defined benefit pension plans to be amortized from accumulated other comprehensive income into net periodic benefit cost in next fiscal year	$ 1,400	$ 1,200

PENSIONS - Reconciliation of Be

PENSIONS - Reconciliation of Benefit Obligation (Details) - Pensions - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of benefit obligation:
Benefit obligation at January 1	$ 51,171	$ 50,376
Service cost	250	313	$ 302
Interest cost	1,687	1,901	2,051
Actuarial (gain)/ loss	(3,265)	873
Foreign currency exchange rate changes	(599)	1,008
Benefit payments	(3,151)	(3,300)
Benefit obligation at December 31	46,093	51,171	$ 50,376
Accumulated benefit obligation	$ 45,300	$ 50,200

PENSIONS - Reconciliation of Fa

PENSIONS - Reconciliation of Fair Value of Plan Assets (Details) - Pensions - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Reconciliation of fair value of plan assets:
Fair value of plan assets at January 1	$ 13,634	$ 12,503
Actual (loss)/ return on plan assets	(249)	1,039
Employer contributions	3,617	2,316
Foreign currency exchange rate changes	(730)	1,076
Benefit payments	(3,151)	(3,300)
Fair value of plan assets at December 31	13,121	13,634
Employer contributions and benefit payment amounts paid from employer assets	$ 3,600	$ 2,300

PENSIONS - Reconciliation of Fu

PENSIONS - Reconciliation of Funded Status (Details) - Pensions - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Reconciliation of funded status:
Projected benefit obligation	$ (46,093)	$ (51,171)	$ (50,376)
Fair value of plan assets	13,121	13,634	$ 12,503
Funded (unfunded) status at end of year	(32,972)	(37,537)
Equity securities
Reconciliation of funded status:
Fair value of plan assets	12,291	9,921
Debt securities
Reconciliation of funded status:
Fair value of plan assets	0	3,047
Cash
Reconciliation of funded status:
Fair value of plan assets	830	666
UK Scheme
Reconciliation of funded status:
Projected benefit obligation	(9,818)	(11,654)
Fair value of plan assets	12,291	12,968
Funded (unfunded) status at end of year	2,473	1,314
Marine Scheme
Reconciliation of funded status:
Projected benefit obligation	(36,275)	(39,517)
Fair value of plan assets	830	666
Funded (unfunded) status at end of year	$ (35,445)	$ (38,851)

PENSIONS - Asset Allocation (De

PENSIONS - Asset Allocation (Details) - Pensions	Dec. 31, 2018	Dec. 31, 2017
Marine Scheme
Pensions:
Target allocation	100.00%	100.00%
Marine Scheme | Cash
Pensions:
Target allocation	100.00%	10000.00%
UK Scheme
Pensions:
Target allocation	100.00%	100.00%
UK Scheme | Equity
Pensions:
Target allocation	100.00%	76.50%
UK Scheme | Bonds
Pensions:
Target allocation	0.00%	23.50%

PENSIONS - Employer Contributio

PENSIONS - Employer Contributions and Payments (Details) - Pensions $ in Thousands	Dec. 31, 2018USD ($)
UK Scheme
Pensions:
Employer contributions	$ 510
Estimated future benefit payments:
2019	330
2020	410
2021	535
2022	355
2023	370
2024 - 2028	2,310
Marine Scheme
Pensions:
Employer contributions	2,900
Estimated future benefit payments:
2019	3,000
2020	3,000
2021	3,000
2022	3,000
2023	3,000
2024 - 2028	$ 12,500

PENSIONS - Assumptions Used (De

PENSIONS - Assumptions Used (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Weighted average assumptions used in calculating benefit obligation:
Rate of compensation increase	2.20%	2.32%
Weighted average assumptions used in calculating net periodic benefit cost:
Rate of compensation increase	2.32%	2.38%
Pensions
Weighted average assumptions used in calculating benefit obligation:
Discount rate	3.90%	3.40%
Weighted average assumptions used in calculating net periodic benefit cost:
Discount rate	3.40%	3.87%
Expected return on plan assets	6.75%	6.75%

SHARE CAPITAL AND SHARE OPTIO_3

SHARE CAPITAL AND SHARE OPTIONS - Share Capital (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended			24 Months Ended
	Nov. 30, 2014	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2017
Share capital:
Common stock, value, authorized		$ 150,000	$ 150,000		$ 150,000
Common stock, value, issued		$ 101,303	101,119		101,119
Shares issued upon exercise of share options (in shares)		184,000
Contributed surplus		$ 200,000	$ 200,000		$ 200,000
Common stock, shares authorized (in shares)		150,000,000	150,000,000		150,000,000
Common shares, par value (in dollars per share)		$ 1	$ 1		$ 1
Common shares, shares issued (in shares)		101,302,404	101,118,289		101,118,289
Common shares, shares outstanding (in shares)		101,302,404	101,118,289		101,118,289
Percent of stock outstanding	5.00%
Repurchase period	2 years
Remaining amount in share repurchase program (in shares)					500,000
Purchase of treasury shares		$ 0	$ 0	$ 8,214	$ 20,500
Common Stock
Share capital:
Shares issued upon exercise of share options (in shares)		184,115	38,000
Equity Swap
Share capital:
Shares acquired by counterparty (in shares)		3,000,000
Shares acquired by counterparty, per share price (in dollars per share)		$ 45.01			$ 45.01

SHARE CAPITAL AND SHARE OPTIO_4

SHARE CAPITAL AND SHARE OPTIONS - Share Options (Details) - USD ($)	1 Months Ended	12 Months Ended
	Feb. 28, 2002	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Share options:
Options, outstanding (in shares)		4,017,000	4,017,000		3,805,000	4,017,000
Weighted average assumptions used:
Expected dividend yield		0.00%
Outstanding:
Options outstanding, beginning of year (in shares)		4,017,000
Options outstanding, granted in period (in shares)		508,000
Options outstanding, exercises in period (in shares)		(184,000)
Options outstanding, forfeitures in period (in shares)		(521,000)
Options outstanding, lapsed in period (in shares)		(15,000)
Option outstanding, end of year (in shares)		3,805,000	4,017,000
Weighted average exercise price:
Weighted average exercise price, options, outstanding, beginning of year (USD per share)		$ 37.92
Weighted average exercise price, options, grants in period (USD per share)		27.20
Weighted average exercise price, options, exercises in period (USD per share)		14.60
Weighted average exercise price, options, forfeitures in period (USD per share)		45.06
Weighted average exercise price, options, lapsed in period (USD per share)		31.46
Weighted average exercise price, options, outstanding, end of year (USD per share)		$ 36.16	$ 37.92
Intrinsic value of share options exercised		$ 2,621,000	$ 286,000	$ 1,326,000
Total fair value of share options fully vested in the year		$ 16,623,000	$ 13,601,000	$ 113,000
Weighted average remaining contractual term, options, outstanding (in years)		2 years 5 months	3 years
Options exercisable, outstanding (in shares)					2,320,000	1,139,000	108,000
Options exercisable, weighted average exercise price (USD per share)					$ 39.02	$ 37.92	$ 2.84
Options exercisable, weighted average remaining contractual term (in years)		1 year 11 months 15 days	2 years 6 months 10 days	10 months
Intrinsic value of share options outstanding and exercisable					$ 0	$ 0	$ 0
Compensation cost		$ 11,748,000	$ 8,777,000	$ 5,830,000
Share options cost capitalized		$ 421,000	$ 1,823,000	$ 822,000
Golar Scheme
Share options:
Options, outstanding (in shares)		4,000,000	3,800,000	3,800,000	3,800,000	4,000,000	3,800,000
Outstanding:
Options outstanding, beginning of year (in shares)		4,000,000	3,800,000
Option outstanding, end of year (in shares)		3,800,000	4,000,000	3,800,000
Employee Stock Options
Weighted average assumptions used:
Risk free interest rate		2.50%	1.80%	1.80%
Expected volatility of common stock		62.50%	54.50%	55.00%
Expected dividend yield		0.00%	0.00%	0.00%
Expected term of options (in years)		3 years 7 months	3 years 10 months	5 years
Outstanding:
Options outstanding, granted in period (in shares)		500,000	400,000
Weighted average exercise price:
Total unrecognized compensation cost					$ 11,300,000
Weighted average period of recognition for unrecognized compensation cost (in years)		1 year 6 months
Employee Stock Options | Golar Scheme
Share options:
Award term until expiration	5 years
Number of shares authorized for grant	0
Employee Stock Options | Golar Scheme | Minimum
Share options:
Award vesting period (in years)	3 years
Employee Stock Options | Golar Scheme | Maximum
Share options:
Award vesting period (in years)	4 years
Employee Stock Options | LTIP
Share options:
Number of shares authorized for grant					3,000,000
Originally Awarded From 2009-2011 | Employee Stock Options
Share options:
Options, outstanding (in shares)		95,138	95,138			95,138
Outstanding:
Options outstanding, beginning of year (in shares)		95,138
Option outstanding, end of year (in shares)			95,138
Weighted average exercise price:
Compensation cost			$ 600,000

ACCUMULATED OTHER COMPREHENSI_3

ACCUMULATED OTHER COMPREHENSIVE LOSS - Schedules of Accumulate Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of the period	$ 1,796,304	$ 1,909,826	$ 1,916,179
Other comprehensive (loss) income income before reclassification	(20,743)	1,773	3,050
Balance at end of the period	1,825,791	1,796,304	1,909,826
Share of affiliates comprehensive (loss) income
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of the period	5,030	3,414	(192)
Other comprehensive (loss) income income before reclassification	(24,324)	1,616	3,606
Balance at end of the period	(19,294)	5,030	3,414
Pension and post retirement benefit plan adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of the period	(12,799)	(12,956)	(12,400)
Other comprehensive (loss) income income before reclassification	3,581	157	(556)
Balance at end of the period	(9,218)	(12,799)	(12,956)
Total accumulated comprehensive (loss) income
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of the period	(7,769)	(9,542)	(12,592)
Balance at end of the period	$ (28,512)	$ (7,769)	$ (9,542)

FINANCIAL INSTRUMENTS - Interes

FINANCIAL INSTRUMENTS - Interest Rate Risk Management (Details) $ / shares in Units, $ in Thousands	12 Months Ended	24 Months Ended
	Dec. 31, 2018USD ($)$ / sharesshares	Dec. 31, 2017USD ($)$ / shares$ / barrel	Dec. 31, 2016USD ($)
Mark-to-market swaps valuation:
Investment in affiliates	$ 571,782	$ 703,225	$ 648,780
Energy Related Derivative
Mark-to-market swaps valuation:
Derivative, floor price (in usd/barrel) | $ / barrel		60
Equity Swap
Mark-to-market swaps valuation:
Shares acquired by counterparty (in shares) | shares	3,000,000
Shares acquired by counterparty, per share price (in dollars per share) | $ / shares	$ 45.01	$ 45.01
Loss on derivative	$ 30,700
Designated as Hedging Instrument | Interest rate swap | Cash flow hedging
Mark-to-market swaps valuation:
Notional value	$ 950,000	$ 1,250,000
Designated as Hedging Instrument | Interest rate swap | Cash flow hedging | Minimum
Mark-to-market swaps valuation:
Fixed interest rate	1.23%	1.13%
Designated as Hedging Instrument | Interest rate swap | Cash flow hedging | Maximum
Mark-to-market swaps valuation:
Fixed interest rate	1.94%	1.94%
Golar Partners
Mark-to-market swaps valuation:
Forward contract to purchase shares (in shares) | shares	107,000
Forward contract to purchase shares, average price per share (in dollars per share) | $ / shares	$ 20.53

FINANCIAL INSTRUMENTS - Fair Va

FINANCIAL INSTRUMENTS - Fair Values (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Oct. 31, 2018	Dec. 31, 2017	Dec. 03, 2017
Carrying Value and Estimated Fair Values
Cash collateral	$ 486,426,000		$ 397,815,000
Derivative asset	95,500,000		112,317,000
Derivative liability	72,126,000		40,364,000
Debt Issuance Costs, Net	16,837,000		24,053,000
Gross amounts presented in the consolidated balance sheet, Total asset derivatives	10,770,000		10,166,000
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	0		0
Net amount, Total asset derivatives	10,770,000		10,166,000
Energy Related Derivative
Carrying Value and Estimated Fair Values
Derivative asset	84,730,000		94,700,000
Derivative liability				$ 79,600,000
Interest rate swap
Carrying Value and Estimated Fair Values
Derivative asset	6,298,000		10,166,000
Equity Swap
Carrying Value and Estimated Fair Values
Derivative liability	70,804,000		40,141,000
Currency swap
Carrying Value and Estimated Fair Values
Derivative asset			51,000
Derivative liability	1,322,000		223,000
Earn-Out Units
Carrying Value and Estimated Fair Values
Derivative asset	0		7,400,000
Level 1 | Carrying value
Carrying Value and Estimated Fair Values
Cash and cash equivalents	217,835,000		214,862,000
Restricted cash and short-term deposits	486,426,000		397,815,000
Level 1 | Fair value
Carrying Value and Estimated Fair Values
Cash and cash equivalents	217,835,000		214,862,000
Restricted cash and short-term deposits	486,426,000		397,815,000
Level 2 | Carrying value
Carrying Value and Estimated Fair Values
Current portion of long-term debt	(732,184,000)		(1,393,229,000)
Long-term debt - convertible bond	(353,661,000)		(340,173,000)
Long-term debt	(1,496,351,000)		(701,498,000)
Level 2 | Carrying value | Energy Related Derivative
Carrying Value and Estimated Fair Values
Derivative asset	84,730,000		94,700,000
Level 2 | Carrying value | Interest rate swap
Carrying Value and Estimated Fair Values
Derivative asset	10,770,000		10,166,000
Level 2 | Carrying value | Equity Swap
Carrying Value and Estimated Fair Values
Derivative liability	70,804,000		40,141,000
Level 2 | Carrying value | Currency swap
Carrying Value and Estimated Fair Values
Foreign exchange swaps asset	0		51,000
Foreign exchange swaps liability	(1,322,000)		(223,000)
Level 2 | Carrying value | Earn-Out Units
Carrying Value and Estimated Fair Values
Derivative asset	0	$ 0	7,400,000
Level 2 | Fair value
Carrying Value and Estimated Fair Values
Current portion of long-term debt	(732,184,000)		(1,393,229,000)
Long-term debt - convertible bond	(373,029,000)		(430,361,000)
Long-term debt	(1,496,351,000)		(701,498,000)
Level 2 | Fair value | Energy Related Derivative
Carrying Value and Estimated Fair Values
Derivative asset	84,730,000		94,700,000
Level 2 | Fair value | Interest rate swap
Carrying Value and Estimated Fair Values
Derivative asset	10,770,000		10,166,000
Level 2 | Fair value | Equity Swap
Carrying Value and Estimated Fair Values
Derivative liability	70,804,000		40,141,000
Level 2 | Fair value | Currency swap
Carrying Value and Estimated Fair Values
Foreign exchange swaps asset	0		51,000
Foreign exchange swaps liability	(1,322,000)		(223,000)
Level 2 | Fair value | Earn-Out Units
Carrying Value and Estimated Fair Values
Derivative asset	0		$ 7,400,000
Share Repurchase Forward Swap
Carrying Value and Estimated Fair Values
Cash collateral	$ 82,900,000
Collateral required under share repurchase agreement, percentage of total purchase price	20.00%

FINANCIAL INSTRUMENTS - Concent

FINANCIAL INSTRUMENTS - Concentrations of Risk (Details)	12 Months Ended
	Dec. 31, 2018USD ($)vessel	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Jul. 06, 2016	Jul. 31, 2013USD ($)
Concentration of risks:
Investments, ownership percentage	100.00%
Investments in affiliates	$ 571,782,000	$ 703,225,000	$ 648,780,000
Golar Partners
Concentration of risks:
Investments, ownership percentage	32.00%	31.80%
Ownership percentage	32.00%	31.80%
Investments in affiliates	$ 271,160,000	$ 467,097,000
Golar Partners | Vessels and equipment
Concentration of risks:
Vessels operated by affiliate | vessel	10
Vessels operated by affiliates, medium to long-term charters | vessel	5
Impairment loss	$ 149,400,000
Golar Power
Concentration of risks:
Ownership percentage	50.00%	50.00%		50.00%
Investments in affiliates	$ 266,151,000	$ 228,696,000
Line of Credit | $1.125 billion newbuild facility | Secured Debt
Concentration of risks:
Maximum borrowing capacity	$ 1,125,000,000				$ 1,125,000,000

RELATED PARTY TRANSACTIONS - Tr

RELATED PARTY TRANSACTIONS - Transactions With Golar Partners and Subsidiaries (Details) - Golar Partners - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	$ 10,230	$ (8,152)	$ (19,559)
Management and administrative services fees
Related Party Transaction [Line Items]
Revenue from related parties	9,809	7,762	4,251
Ship management fees revenue
Related Party Transaction [Line Items]
Revenue from related parties	5,200	5,903	6,466
Charter-hire expenses
Related Party Transaction [Line Items]
Related party expense	0	(17,423)	(28,368)
Interest expense on short-term credit facility
Related Party Transaction [Line Items]
Interest expense from related parties	0	0	(122)
Share options expense recharge
Related Party Transaction [Line Items]
Revenue from related parties	0	228	181
Interest Expense on Deposit Payable
Related Party Transaction [Line Items]
Interest expense from related parties	$ (4,779)	$ (4,622)	$ (1,967)

RELATED PARTY TRANSACTIONS RELA

RELATED PARTY TRANSACTIONS RELATED PARTY TRANSACTIONS - Balances with Golar Partners and Subsidiaries (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 43,977	$ 14,010
Golar Partners
Related Party Transaction [Line Items]
Amount due from (to) related party	1,256	(184,855)
Golar Partners | Trading balances with affiliates
Related Party Transaction [Line Items]
Amount due from (to) related party	4,091	(4,144)
Golar Partners | Methane Princess lease security deposit movements
Related Party Transaction [Line Items]
Amount due from (to) related party	(2,835)	(3,464)
Golar Partners | Deposits payable
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 0	$ (177,247)

RELATED PARTY TRANSACTIONS - _2

RELATED PARTY TRANSACTIONS - Transactions/balances with Golar Partners and Subsidiaries Narrative (Details) - Golar Partners $ in Millions	Aug. 15, 2017USD ($)train	May 31, 2017USD ($)	Feb. 29, 2016	Jan. 31, 2016USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	May 31, 2016USD ($)
Related Party Transaction [Line Items]
Related party transaction, rate					5.00%
Duration of notice required for contract termination (in days)					120 days
Ship management fees income
Related Party Transaction [Line Items]
Duration of notice required for contract termination (in days)					30 days
Charter-hire expenses, Golar Grand
Related Party Transaction [Line Items]
Related party expense						$ 17.4	$ 28.4
Amortization in respect of the guarantee obligation						5.1	6.1
Deferred Purchase Price
Related Party Transaction [Line Items]
Related party transaction, rate		5.00%
Interest expense from related parties					$ 2.9	1.1
Purchases from related party		$ 107.2
Hilli Sale Agreement
Related Party Transaction [Line Items]
Interest expense from related parties					1.9	1.3
Deposit Received
Related Party Transaction [Line Items]
Related party transaction, rate	5.00%
Related party transaction amount	$ 70
Line of Credit | Golar LNG Partners Credit Facility
Related Party Transaction [Line Items]
Proceeds from short-term credit facility with Golar Partners				$ 30
Short-term credit facility repayment period				60 days
Line of Credit | LIBOR | Golar LNG Partners Credit Facility
Related Party Transaction [Line Items]
Related party transaction, rate				5.00%
Golar Tundra
Related Party Transaction [Line Items]
Purchase price								$ 107.2
Right to require repurchase if charter has not commenced, period post closing			12 months
Interest expense from related parties					$ 0	$ 2.2	$ 2
Hilli Sale Agreement
Related Party Transaction [Line Items]
Purchase price	$ 658
Percentage of net lease obligation under credit facility	50.00%
Interest in liquefaction trains, percent	50.00%
Number of liquefaction trains | train	2
Related party transaction, term of agreement (in years)	8 years

RELATED PARTY TRANSACTIONS - Ot

RELATED PARTY TRANSACTIONS - Other Transactions, Indemnifications and Guarantees (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 24, 2018	Nov. 15, 2017	Oct. 13, 2016	Oct. 12, 2016	Nov. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Dividends received						$ 15,837	$ 27,553	$ 26,515
Minimum quarterly distribution per unit (in dollars per share)	$ 0.4042		$ 0.5775	$ 0.3850
Guarantees issued to Golar Partners						14,770	11,429
Dividends payable						16,762	5,032
Golar Partners
Related Party Transaction [Line Items]
Dividends received		$ 900				$ 48,400	52,300	$ 54,700
Minimum charter term for rights of first offer (in years)						5 years
Golar Partners | Tax lease indemnification
Related Party Transaction [Line Items]
Guarantees issued to Golar Partners						$ 11,500	$ 11,500
Golar Partners, Common Unit
Related Party Transaction [Line Items]
Number of units (in shares)		374,295	2,994,364
Number of earn-out units (in shares)			748,592		374,295
Golar Partners, General Partner Units
Related Party Transaction [Line Items]
Number of units (in shares)		7,639	61,109
Number of earn-out units (in shares)			15,278		7,639
Hilli LLC | Golar Partners
Related Party Transaction [Line Items]
Payments of dividends						5,600
Golar Hilli LLC | Golar Partners
Related Party Transaction [Line Items]
Dividends payable						3,600
Golar Partners
Related Party Transaction [Line Items]
Guarantor obligations, maximum exposure, undiscounted						$ 20,000

RELATED PARTY TRANSACTIONS - _3

RELATED PARTY TRANSACTIONS - Transactions with Golar Power and Affiliates (Details) - Golar Power - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	$ 8,181	$ 7,445	$ 2,788
Management and administrative services revenue
Related Party Transaction [Line Items]
Revenue from related parties	6,167	5,711	1,965
Ship management fees income
Related Party Transaction [Line Items]
Revenue from related parties	1,400	824	335
Surety bond and debt guarantee compensation
Related Party Transaction [Line Items]
Related party transaction amount	861	775	488
Share options expense recharge
Related Party Transaction [Line Items]
Related party transaction amount	$ (247)	$ 135	$ 0

RELATED PARTY TRANSACTIONS - Ba

RELATED PARTY TRANSACTIONS - Balances with Golar Power and Affiliates (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 43,977	$ 14,010
Golar Power
Related Party Transaction [Line Items]
Amount due from (to) related party	(5,417)	(935)
Golar Power | Trading balances with affiliates
Related Party Transaction [Line Items]
Amount due from (to) related party	$ (5,417)	$ (935)

RELATED PARTY TRANSACTIONS - Go

RELATED PARTY TRANSACTIONS - Golar Power Other Transactions, Indemnifications and Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Golar Power | Debt guarantees
Related Party Transaction [Line Items]
Amount of guarantee	$ 393.5	$ 182.3

RELATED PARTY TRANSACTIONS - _4

RELATED PARTY TRANSACTIONS - Transactions with OneLNG and Subsidiaries (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
OneLNG | Management and administrative services revenue
Related Party Transaction [Line Items]
Revenue from related parties	$ 1,399	$ 6,463	$ 586

RELATED PARTY TRANSACTIONS - _5

RELATED PARTY TRANSACTIONS - Transactions with OneLNG and Subsidiaries Narrative (Details) - USD ($) $ in Thousands	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 43,977	$ 14,010
OneLNG | Trading balances with affiliates
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 8,169	$ 7,898

RELATED PARTY TRANSACTIONS - _6

RELATED PARTY TRANSACTIONS - Balances with OneLNG and Subsidiaries (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amount due from (to) related party	$ 43,977	$ 14,010
OneLNG | Trading balances with affiliates
Related Party Transaction [Line Items]
Impairment of related party transaction, due from (to) related party	12,700
Amount due from (to) related party	8,169	$ 7,898
OneLNG | Gandria Conversion
Related Party Transaction [Line Items]
Impairment of related party transaction, due from (to) related party	$ 1,300

RELATED PARTY TRANSACTIONS - _7

RELATED PARTY TRANSACTIONS - Other Related Parties (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Net income (expense from transactions with related party	$ 150,777	$ 59,578	$ 27,972
Amount due from (to) related party	43,977	14,010
Vessel operating expenses	(96,860)	(55,946)	(53,163)
Collaborative Arrangement
Related Party Transaction [Line Items]
Time and voyage charter revenues	73,931	28,327	13,730
Voyage, charter-hire and commission expenses	(83,201)	(38,781)	(11,140)
The Cool Pool Limited
Related Party Transaction [Line Items]
Time and voyage charter revenues	177,139	77,975	37,345
Vessel operating expenses	(16,717)	(7,683)	(7,681)
The Cool Pool Limited
Related Party Transaction [Line Items]
Net income (expense from transactions with related party	151,152	59,838	32,254
Amount due from (to) related party	43,985	14,004
The Cool Pool Limited | The Cool Pool Limited
Related Party Transaction [Line Items]
Net income (expense from transactions with related party	151,152	59,838	32,254
Magni Partners
Related Party Transaction [Line Items]
Net income (expense from transactions with related party	(375)	(260)	(4,282)
Amount due from (to) related party	(8)	6
Magni Partners | Recharge for Advisory Services
Related Party Transaction [Line Items]
Due to related parties	400	300	3,900
Magni Partners | Recharge for Disposal of Golar Power
Related Party Transaction [Line Items]
Due to related parties			$ 3,000
Magni Partners | Recharge for Board Member Travel
Related Party Transaction [Line Items]
Due to related parties	$ 40	300
Magni Partners | Recharge for Other Travel and Out of Pocket Expenses
Related Party Transaction [Line Items]
Due to related parties		$ 300

CAPITAL COMMITMENTS (Details)

CAPITAL COMMITMENTS (Details) - USD ($) $ in Thousands	1 Months Ended
	Feb. 28, 2019	Dec. 31, 2018
Hilli Conversion to FLNGV
Capital commitments:
Purchase obligation, due in next twelve months		$ 21,530
Purchase obligation		$ 21,530
Subsequent Event | Gimi Conversion
Capital commitments:
Long-term purchase commitment, period	20 years
Long-term purchase commitment, amount	$ 1,300,000

OTHER COMMITMENTS AND CONTING_3

OTHER COMMITMENTS AND CONTINGENCIES (Details) $ / shares in Units, $ in Thousands, € in Millions, £ in Millions	Oct. 01, 2018USD ($)	Nov. 30, 2018$ / sharesshares	Dec. 31, 2018USD ($)tax_leaseplant$ / sharesshares	Dec. 31, 2018GBP (£)tax_lease	Dec. 31, 2003GBP (£)tax_lease	Jun. 30, 2019EUR (€)	Dec. 31, 2018EUR (€)plantshares	Dec. 31, 2017USD ($)$ / sharesshares	Mar. 03, 2017shares	Dec. 31, 2016USD ($)
Tax lease benefits:
Book value of vessels secured against long-term loans			$ 3,244,291					$ 2,032,747
Number of tax leases | tax_lease					6
Gross amount received from tax lease benefit (in GBP) | £					£ 41
Number of tax leases terminated | tax_lease			5	5
Other commitment to pay third party			$ 1,000
Number of power plants | plant			2				2
Contractual obligation | €							€ 0.5
Investments in affiliates			$ 571,782					$ 703,225		$ 648,780
Common shares, par value (in dollars per share) | $ / shares			$ 1					$ 1
Minimum
Tax lease benefits:
Estimate of possible exposure | £				£ 0
Maximum
Tax lease benefits:
Estimate of possible exposure | £				£ 115
Golar Partners
Tax lease benefits:
Number of tax leases remaining | tax_lease			1	1
Secured Debt | Margin Loan Facility
Tax lease benefits:
Common units, pledged as collateral | shares			21,226,586				21,226,586	20,852,291	20,852,291
Scenario, Forecast
Tax lease benefits:
Contractual obligation | €						€ 15
Avenir LNG Ltd
Tax lease benefits:
Ownership percentage	25.00%
Investment company, financial commitment, future amount			$ 18,000
Avenir LNG Ltd | Stolt-Nielsen Ltd and Höegh LNG Holdings Ltd
Tax lease benefits:
Investment company, committed capital	$ 182,000
Other Operating Income
Tax lease benefits:
Loss contingency, receivable, proceeds			50,700
Founding Partners | Avenir LNG Ltd
Tax lease benefits:
Investment company, financial commitment, future amount			$ 72,000
Avenir LNG Ltd
Tax lease benefits:
Stock issued during period (in shares) | shares		110,000,000
Common shares, par value (in dollars per share) | $ / shares		$ 1

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Subsequent Event - USD ($) $ / shares in Units, $ in Millions	1 Months Ended
	Mar. 27, 2019	Feb. 28, 2019	Jan. 31, 2019	Feb. 27, 2019
Subsequent events:
Dividend declared (in dollars per share)	$ 0.15
Golar Partners
Subsequent events:
Cash distribution per share (in dollars per share)				$ 0.40
Proceeds from dividends	$ 9.2
Golar Viking Converted to FSRU
Subsequent events:
Term of sale leaseback transaction			10 years
Gimi Conversion
Subsequent events:
Long-term purchase commitment, period		20 years
Long-term purchase commitment, amount		$ 1,300
Long-term line of credit				$ 700
Expected future revenues, net of operating costs		$ 215