Golar LNG Limited (GLNG) 6-K 5 Sep 19 2019 Q2 Current report (foreign) Financial data

Cover Page

Cover Page	6 Months Ended
	Jun. 30, 2019
Cover page.
Entity Registrant Name	GOLAR LNG LTD
Entity Central Index Key	0001207179
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Document Type	6-K
Amendment Flag	false
Document Period End Date	Jun. 30, 2019

UNAUDITED CONSOLIDATED STATEMEN

UNAUDITED CONSOLIDATED STATEMENTS OF (LOSS)/INCOME - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Total operating revenues	$ 211,032	$ 125,564
Vessel operating expenses	(62,066)	(38,911)
Administrative expenses	(27,705)	(24,092)
Project development expenses	(1,467)	(11,223)
Depreciation and amortization	(56,284)	(36,866)
Asset Impairment Charges	41,597	0
Impairment of long-term assets	(7,347)	0
Total operating expenses	(220,046)	(152,096)
Realized and unrealized gain on oil derivative instrument	8,145	111,348
Other operating gains and losses	6,298	18
Total other operating income	14,443	111,366
Operating income	5,429	84,834
Financial income/(expenses)
Interest income	6,437	4,044
Interest expense	(53,728)	(38,012)
(Losses)/gains on derivative instruments	(20,418)	1,068
Other financial items, net	(3,339)	(474)
Net financial expenses	(71,048)	(33,374)
(Loss)/income before taxes and equity in net losses of affiliates	(65,619)	51,460
Income taxes	(381)	(484)
Equity in net losses of affiliates	(39,869)	(6,215)
Net (loss)/income	(105,869)	44,761
Net income attributable to non-controlling interests	(48,554)	(29,444)
Net (loss)/income attributable to stockholders of Golar LNG Limited	$ (154,423)	$ 15,317
Basic and diluted loss per share (in USD per share)	$ (1.53)	$ 0.15
Cash dividends declared and paid per share (in USD per share)	$ 0.15	$ 0.10
Non-collaborative Arrangement
Voyage, charterhire and commission expenses	$ (11,994)	$ (10,107)
Collaborative Arrangement
Voyage, charterhire and commission expenses	(18,933)	(30,897)
Time and Voyage Charter
Total operating revenues	68,031	76,433
Time Charter
Total operating revenues	23,359	19,353
Liquefaction Services
Total operating revenues	109,048	18,577
Vessel and Other Management Fees
Total operating revenues	$ 10,594	$ 11,201

UNAUDITED CONSOLIDATED STATEM_2

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
Net (loss)/income	$ (105,869)	$ 44,761
Other comprehensive income/(loss):
Net gain/(loss) on foreign currency translation	651	(24,137)
Other comprehensive income/(loss)	651	(24,137)
Comprehensive (loss)/income	(105,218)	20,624
Comprehensive (loss)/income attributable to:
Stockholders of Golar LNG Limited	(153,772)	(8,820)
Non-controlling interests	$ 48,554	$ 29,444

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands		Jun. 30, 2019	Dec. 31, 2018
Current
Cash and cash equivalents		$ 139,834	$ 217,835
Restricted cash and short-term deposits		252,843	332,033
Trade accounts receivable	[1]	33,720	64,918
Inventories		8,195	7,006
Other current assets		14,625	18,720
Amounts due from related parties		5,207	9,425
Total current assets		454,424	649,937
Non-current
Restricted cash		152,743	154,393
Investments in affiliates		522,538	571,782
Asset under development		186,960	20,000
Vessels and equipment, net		3,190,969	3,271,379
Other non-current assets		116,663	139,104
Total assets		4,624,297	4,806,595
Current
Current portion of long-term debt and short-term debt		(802,323)	(730,257)
Trade accounts payable		(45,411)	(9,701)
Accrued expenses		(70,292)	(133,234)
Other current liabilities		(128,136)	(121,529)
Amounts due to related parties		(4,719)	(5,417)
Total current liabilities		(1,050,881)	(1,000,138)
Non-current
Long-term debt		(1,665,185)	(1,835,102)
Other non-current liabilities		(147,717)	(145,564)
Total liabilities		(2,863,783)	(2,980,804)
Equity
Stockholders' equity		(1,577,063)	(1,745,125)
Non-controlling interests		(183,451)	(80,666)
Total liabilities and stockholders' equity		$ (4,624,297)	$ (4,806,595)
[1]

UNAUDITED CONSOLIDATED STATEM_3

UNAUDITED CONSOLIDATED STATEMENTS OF CASHFLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
OPERATING ACTIVITIES
Net (loss)/income	$ (105,869)	$ 44,761
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	56,284	36,866
Impairment of non-current assets	7,347	0
Impairment of long-lived assets	34,250	0
Amortization of deferred charges and debt guarantees	2,712	5,035
Equity in net (losses) of affiliates	39,869	6,215
Dividends received	0	8,119
Drydocking expenditure	(7,001)	0
Compensation cost related to employee stock awards	5,008	5,367
Net foreign exchange loss	573	618
Change in fair value of derivative instruments	25,152	1,528
Change in fair value of oil derivative instrument	(750)	(108,300)
Change in assets and liabilities:
Trade accounts receivable	31,198	(12,880)
Inventories	(1,189)	(35)
Other current and non-current assets	(11,790)	6,443
Amounts due to related companies	(5,778)	5,687
Trade accounts payable	164	(5,135)
Accrued expenses	(57,268)	15,008
Other current and non-current liabilities	(2,640)	39,037
Net cash provided by operating activities	10,272	48,334
INVESTING ACTIVITIES
Additions to vessels and equipment	(12,178)	(1,801)
Additions to asset under development	(105,339)	(116,715)
Additions to investments in affiliates	(8,292)	(62,244)
Dividends received	18,408	18,335
Proceeds from disposals to Golar Partners	9,652	0
Proceeds from subscription of equity interest in Gimi MS Corporation	72,236	0
Proceeds from disposal of fixed assets	3,160	0
Net cash used in investing activities	(22,353)	(162,425)
FINANCING ACTIVITIES
Proceeds from short-term and long-term debt	14,824	1,176,000
Repayments of short-term and long-term debt	(123,495)	(874,256)
Cash effect of consolidating Hilli Lessor VIE	0	36,532
Cash dividends paid	(38,089)	(9,906)
Proceeds from exercise of share options	0	1,183
Financing costs paid	0	(754)
Net cash (used in)/provided by financing activities	(146,760)	328,799
Net increase in cash, cash equivalents and restricted cash	(158,841)	214,708
Cash, cash equivalents and restricted cash at beginning of period	704,261	612,677
Cash, cash equivalents and restricted cash at end of period	$ 545,420	$ 827,385

UNAUDITED CONSOLIDATED STATEM_4

UNAUDITED CONSOLIDATED STATEMENTS OF CASHFLOWS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Statement of Cash Flows [Abstract]
Cash and cash equivalents	$ 139,834	$ 217,835	$ 375,067	$ 214,862
Restricted cash and short-term deposits (current portion)	252,843	332,033	276,289	222,265
Long-term restricted cash	152,743	154,393	176,029	175,550
Cash, cash equivalents, restricted cash and restricted cash equivalents	$ 545,420	$ 704,261	$ 827,385	$ 612,677

UNAUDITED CONSOLIDATED STATEM_5

UNAUDITED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Share Capital	Treasury Shares	Additional Paid-in Capital	Contributed Surplus	[1]	Accumulated Other Comprehensive Loss	Accumulated Retained (Losses)/Earnings	Total before Non- controlling Interests	Non-controlling Interest
Beginning balance at Dec. 31, 2017	$ 1,796,304	$ 101,119	$ (20,483)	$ 1,538,191	$ 200,000		$ (7,769)	$ (95,742)	$ 1,715,316	$ 80,988
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss)/income	44,761							15,317	15,317	29,444
Dividends	(9,906)							(9,906)	(9,906)
Exercise of share options	1,183	120		1,063					1,183
Grant of employee stock compensation	7,214			7,214					7,214
Forfeiture of employee stock compensation	(1,426)			(1,426)					(1,426)
Proceeds from subscription of equity interest in Gimi MS Corporation (note 9)	28,702									28,702
Other comprehensive loss/income	(24,137)						(24,137)		(24,137)
Ending balance at Jun. 30, 2018	1,842,695	101,239	(20,483)	1,545,042	200,000		(31,906)	(90,331)	1,703,561	139,134
Beginning balance at Dec. 31, 2018	1,825,791	101,303	(20,483)	1,857,196	200,000		(28,512)	(364,379)	1,745,125	80,666
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss)/income	(105,869)							(154,423)	(154,423)	48,554
Dividends	(37,304)							(29,288)	(29,288)	(8,016)
Grant of employee stock compensation	5,097			5,097					5,097
Forfeiture of employee stock compensation	(88)			(88)					(88)
Proceeds from subscription of equity interest in Gimi MS Corporation (note 9)	72,236			9,989					9,989	62,247
Other comprehensive loss/income	651						651		651
Ending balance at Jun. 30, 2019	$ 1,760,514	$ 101,303	$ (20,483)	$ 1,872,194	$ 200,000		$ (27,861)	$ (548,090)	$ 1,577,063	$ 183,451
[1]	Contributed Surplus is 'capital' that can be returned to shareholders without the need to reduce share capital, thereby giving us greater flexibility when it comes to declaring dividends.

General

General	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	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 June 30, 2019, 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. Gimi MS Corporation In April 2019, Gimi MS Corporation ("Gimi MS") entered into a Subscription Agreement with First FLNG Holdings Pte. Ltd. ("First FLNG Holdings"), an indirect wholly-owned subsidiary of Keppel Capital, in respect of their participation in a 30% share of FLNG Gimi . Gimi MS will construct, own and operate FLNG Gimi and First FLNG Holdings will subscribe for 30% of the total issued ordinary share capital of Gimi MS for a subscription price equivalent to 30% of the project cost. Under the Subscription Agreement, Gimi MS may call for cash from the shareholders for any future funding requirements and shareholders are required to contribute to such cash calls up to a defined cash call contribution. The Gimi is currently undergoing its FLNG conversion with an expected completion and redelivery date in 2022. Going concern The condensed consolidated financial statements have been prepared on a going concern basis. As previously disclosed in our annual financial statements for the year ended December 31, 2018, note 5, a pre-condition of the Golar Tundra lease financing with CMBL, is for the vessel 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 were required to find a replacement charter by June 30, 2019 or we could be required to refinance the FSRU. In May 2019, the June 2019 call option date was extended to June 2021. In February 2019, Golar entered into an agreement with BP for the charter of a FLNG unit, the Gimi, after conversion, for a 20 -year period expected to commence in the second half of 2022. 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 $215.0 million . Golar has received a $700 million underwritten financing commitment for a long-term financing facility, which is subject to the satisfaction of certain conditions by the parties and final documentation. The facility will be available during the Gimi conversion and has a tenure of 7 years post commissioning and a 12 year amortization profile. To address our anticipated capital expenditure (in particular those associated with our initial commitments related to the Gimi conversion) and working capital requirements over the next 12 months, we are in ongoing discussions with various financial institutions for funding sources which we could utilize for the funding of our capital commitments, investments, working capital and the scheduled repayments of long and short-term debt balances. While we believe we will be able to obtain the necessary funds and have a track record of successfully financing our conversion projects, we cannot be certain that the proposed new credit facilities will be executed in time or at all. In addition, if market and economic conditions are favorable, we may also consider further issuances of corporate debt or equity to increase liquidity. 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. 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 from September 5, 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 prudent revenue contributions from our fleet and full operating costs, and accordingly are confident of our ability to manage through the near term cash requirements.

Accounting Policies

Accounting Policies	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Accounting Policies	ACCOUNTING POLICIES Basis of accounting The condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States ("U.S. GAAP"). The condensed consolidated financial statements do not include all of the disclosures required under U.S. GAAP in the annual consolidated financial statements, and should be read in conjunction with our audited annual financial statements for the year ended December 31, 2018, which are included in our annual report on Form 20-F. Significant accounting policies The accounting policies adopted in the preparation of the condensed consolidated financial statements for the six months ended June 30, 2019 are consistent with those followed in the preparation of our audited consolidated financial statements for the year ended December 31, 2018, except for "Leases" as a result of adopting the requirements of ASU 2016-02 “Leases (Topic 842)”(hereafter, ASC 842). Our revenue contracts and related expense recognition Contracts relating to our LNG carriers, FSRUs and FLNG asset can take the form of operating leases, finance leases, tolling agreements and management agreements. In addition, we contract a portion of our vessels in the spot market through our collaborative arrangement, the "Cool Pool". Although the substance of these contracts are similar, (they allow our customers to hire our assets and to avail of Golar's management services for a specified day rate) the accounting treatment varies. We outline our policies for determining the appropriate GAAP treatment below. Lease accounting versus revenue accounting To determine whether a contract conveys a lease agreement for a period of time, the Group has assessed whether, throughout the period of use, the customer has both of the following: • the right to obtain substantially all of the economic benefits from the use of the identified asset; and • the right to direct the use of that identified asset. If a contract relating to an asset fails to give the customer both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e. another third party could contract for a meaningful amount of the asset capacity). In situations where we provide management services unrelated to an asset contract, we account for the contract as a revenue contract. Lease accounting When a contract is designated as a lease, we make an assessment on whether the contract is an operating lease or a finance lease. An agreement will be a finance lease if any of the following conditions are met: • ownership of the asset is transferred at the end of the lease term; • the contract contains an option to purchase the asset which is reasonably certain to be exercised; • the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the asset's useful life are not subject to this criterion; • the discounted value of the fixed payments under the lease represent substantially all of the fair value of the asset; or • the asset is heavily customized such that it could not be used for another charter at the end of the term. Lessor accounting In making the classification assessment, we estimate the residual value of the underlying asset at the end of the lease term with reference to broker valuations. None of our lease contracts contain residual value guarantees and any purchase options are disclosed in note 9. Agreements which include renewal and termination options are included in the lease term if we believe they are "reasonably certain" to be exercised by the lessee or if controlled by the lessor. The determination of whether lessee extension clauses are reasonably certain depends whether the option contains an economic incentive. Generally, lease accounting commences when the asset is made available to the customer, however, where the contract contains specific customer acceptance testing conditions, lease accounting will not commence until the asset has successfully passed the acceptance test. We assess a lease under the modification guidance when there is a change to the terms and conditions of the contract that results in a change in the scope or the consideration of the lease. Costs directly associated with the execution of the lease or costs incurred after lease inception (the execution of the contract) but prior to the commencement of the lease that directly relate to preparing the asset for the contract (for example bunker costs), are capitalized and amortized to the consolidated statement of income over the lease term. We also defer upfront revenue payments (for example positioning fees) to the consolidated balance sheet and amortize to the consolidated statement of income over the lease term. Fixed revenue from operating leases is accounted for on a straight line basis over the life of the lease; while variable revenue is accounted for as incurred in the relevant period. Fixed revenue includes fixed payments and variable payments based on a rate or index. For our operating leases, we have elected the practical expedient to combine our service revenue and operating lease income as both the timing and the pattern of transfer of the components are the same. On inception of a finance lease, we derecognize the related asset and record a "net investment in finance lease" financial asset on our consolidated balance sheet. The net investment represents the fixed payments due from the lessee and unguaranteed residual value, discounted at the discount rate implicit in the lease. We recognize finance lease income in the consolidated statement of income (“interest income”) to reflect the implicit rate of interest applied to the outstanding financial asset balance. Revenue accounting Contracts within the scope of revenue accounting include our liquefaction services contract relating to the Hilli asset and our management fee services provided to our affiliates (Golar Partners and Golar Power) and customers who lease our assets under finance lease arrangements. For liquefaction services revenue, the provision of liquefaction services capacity is considered a single performance obligation recognised evenly over time. We consider our services (the receipt of customer's gas, treatment and temporary storage on board our FLNG and delivery of LNG to waiting carriers) to be a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. 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. Contractual payment terms for liquefaction services is monthly in arrears. Contract liabilities arise when the customer makes payments in advance of receiving services. The period between when invoicing and when payment is due is not significant. Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. The management services we provide 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. 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 that we have the right to invoice. Our contracts generally have an initial term of one year or less, after which the arrangement continues with a short notice period until the end of the contract, ranging from 30 days to 180 days. Contract assets arise when we render management services in advance of receiving payment from our customers. Derivatives Changes in presentation of fair value of derivative instruments and oil derivative instrument Effective from the quarter ended September 30, 2018, we presented two new line items in operating activities on the face of the statements of cash flows. Given the significance of the oil derivative instrument in the current year, we believe that the introduction of this new line item in the statements of cash flows provides users of our financial statements with 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 period ended June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted Change in fair value of derivative instruments — 1,528 1,528 Change in fair value of oil derivative instrument — (108,300 ) (108,300 ) Change in assets and liabilities: Other current and non-current assets (105,056 ) 111,499 6,443 Other current and non-current liabilities 43,764 (4,727 ) 39,037 Gains/(losses) on derivative instruments Effective from the quarter ended September 30, 2018, we presented a new line item under financial income/(expense) on the face of the statements of income. The new line item, "Losses 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 these new line items will provide users of our financial statements with greater transparency over our derivative instruments. This presentation change has been retrospectively applied for all prior periods. The change in presentation for the six months ended June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments Increase/ (Decrease) As adjusted Gains on derivative instruments — 1,068 1,068 Other financial items, net 594 (1,068 ) (474 ) Oil Derivative Instrument In relation to the oil derivative instrument, 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 Liquefication 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 necessary to blend the long and 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 within "Realized and unrealized gain on oil derivative instrument" as part of the consolidated statement of income. The realized and unrealized gain on oil derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2019 2018 Realized gain on oil derivative instrument 7,395 3,048 Unrealized gain on oil derivative instrument 750 108,300 8,145 111,348 For further information on the nature of this derivative, refer to note 16. The unrealized gain results from movement in oil prices above a contractual floor price over term of the LTA; whereas the realized gain results from monthly billings above the base tolling fee under the LTA. Impairment of non-current assets In March 2019, we entered into a number of contracts relating to the conversion and subsequent disposal of the Golar Viking. As of March 31, 2019, although we were still awaiting on LNG Hrvatska to issue Golar a final notice to proceed, we determined that there was sufficient probability of the sale being finalized to trigger an impairment test on the vessel. The impairment test resulted in a charge of $34.3 million . The fair value of the LNG carrier Golar Viking is categorized within level 2 of the fair value hierarchy, and is based on the average of third party broker valuations. The fair value does not factor in any cash flows associated with the conversion project. The value represents the price that a market participant would pay for a LNG carrier as this is the principal market for the vessel. This is consistent with the fair value methodology that we use for all of our LNG carriers. In May 2019, a major shareholder of OLT Offshore LNG Toscana S.P.A. (OLT-O) sold its shareholdings which triggered a re-assessment of the carrying value of our investment in OLT-O that was previously recorded at a measurement alternative of cost less impairment as no readily determinable fair value was available. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O to its fair value. Use of estimates The preparation of financial statements in accordance with United States Generally Accepted Accounting Principles ("U.S. 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 June 30, 2019, we leased eight vessels under finance leases 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 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.

Recently Issued Accounting Stan

Recently Issued Accounting Standards	6 Months Ended
	Jun. 30, 2019
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recently Issued Accounting Standards	RECENTLY ISSUED ACCOUNTING STANDARDS Adoption of new accounting standards In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) along with subsequent amendments ASU 2019-20 Leases (Topic 842): Narrow scope improvements for lessors in December 2018 and ASU 2019-01 Leases (Topic 842): Codification improvements in March 2019. Topic 842 modifies the definition of a lease, requires reassessment of the lease term upon the occurrence of certain triggers and introduces new disclosures. Lessors are required to classify leases as sales-type, direct financing or operating, with classification affecting the pattern of income recognition and provide 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. We adopted this Topic 842 on January 1, 2019 under a modified retrospective transition approach. In contracts where we act as either the lessor or lessee, we have elected to use the "package" of practical expedients available, which means no reassessment on transition of whether an agreement contains a lease, lease classification, and initial direct costs under ASC 842. As part of this package the lease term has been determined using hindsight up to the date of transition when considering lessee options to extend or terminate the agreement or to purchase the underlying asset. Furthermore, where available we have elected not to separate the components in our lease arrangements, instead accounting for them on a combined component basis under ASC 842. 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. The impact on the Company of applying ASU 842 as a lessee, based on contractual arrangements in place at December 31, 2018, was the recognition of lease liabilities of $15.8 million , along with right-of-use assets with a similar aggregate value, which mainly relates to our office leases. This liability corresponds to our lessee related liability for future lease payments presented on the face of the consolidated balance sheet as other current liabilities of $5.5 million and other non-current liabilities of $10.3 million , while the carrying value of the lessee right-of-use assets is disclosed in note 13 to these condensed consolidated financial statements. For contracts where we are the lessor, the practical expedients that we have elected has resulted 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 have been assessed under the requirements of Topic 842. New lessor presentation and disclosure requirements have been applied to our new and existing lease agreements. The carrying value of the assets subject to lessor operating leases, and the maturity analysis of operating lease payments under arrangements where we are the lessor, are disclosed in note 8 to the condensed consolidated financial statements. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics including primarily minor corrections, clarifications and codification improvements. We adopted the codification improvements that were not effective on issuance on January 1, 2019 under the specified transition approach connected with each of the codification improvements. This amendment has not had a material impact on our consolidated financial statements or related disclosures, including retained earnings, as January 1, 2019. Accounting pronouncements that have been issued but not adopted The following table provides a brief description of recent accounting standards that have been issued but not yet adopted: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and subsequent amendments, including ASU 2018-19 & ASU 2019-04 Codification Improvements to Topic 326 ‘‘Financial Instruments-Credit Losses” Replaces the incurred loss impairment methodology with an expected loss methodology that requires a consideration of a broader range of reasonable and supportable information to inform credit loss estimates. January 1, 2020 Under evaluation ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement Removes some disclosure requirements relating to transfers between Level 1 and Level 2 of the FV hierarchy. Introduces new disclosure requirements for Level 3 measurements January 1, 2020 No material impact on our disclosure requirements as we have no Level 3 measurements. ASU 2018-14 Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans . Removes some disclosure requirements that are not expected to materially change Golar’s existing note. Introduces new disclosure requirements including an explanation of the reasons for significant gains and losses relating to changes in the benefit obligation. January 1, 2021 No material impact on disclosure requirements. 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 . Aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal use software. January 1, 2020 No material impact on disclosure requirements. ASU 2018-17 Consolidation (Topic 810) - Targeted Improvements to Related Party Guidance for Variable Interest Entities For the purposes of determining whether a decision making fee is a variable interest, a company is now required to consider indirect interests held through related parties under common control on a proportionate basis as opposed to as a direct investment in the entity. January 1, 2020 No impact on historical consolidation assessments. ASU 2018-18 Collaborative Arrangements (Topic 808) - Clarifying the Interaction between Topic 808 and Topic 606 . Provides guidance on determining when transactions between collaborative arrangement participants should be accounted for as revenue under 606. January 1, 2020 Under evaluation

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION We own and operate LNG carriers, a FLNG and FSRUs and provide these services under time charters under varying periods. 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 net 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 June 30, 2019, we operate in the following three reportable segments: • Vessel operations – We operate and subsequently charter out vessels on fixed terms to customers. • FLNG – In 2014, we ordered our first FLNG based on the conversion of our existing LNG carrier, the Hilli. The Hilli FLNG conversion has been completed and the vessel was accepted by the customer under the LTA on May 31, 2018. 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. 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. In December 2018, we entered into a FLNG conversion contract for our existing LNG Carrier, the Gimi . See note 11. • 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. Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 101,984 109,048 — — 211,032 106,987 18,577 — — 125,564 Depreciation and amortization (32,182 ) (24,102 ) — — (56,284 ) (32,775 ) (4,091 ) — — (36,866 ) Other operating expenses (93,305 ) (28,860 ) — — (122,165 ) (103,058 ) (12,172 ) — — (115,230 ) Impairment of long-term assets (2) (3) (41,597 ) — — — (41,597 ) — — — — — Other operating gains (note 18) 9,260 5,183 — — 14,443 10,000 101,366 — — 111,366 Operating (loss)/income (55,840 ) 61,269 — — 5,429 (18,846 ) 103,680 — — 84,834 Inter segment operating income/(loss) (4) 342 — — (342 ) — 205 — — (205 ) — Segment operating/(loss) income (55,498 ) 61,269 — (342 ) 5,429 (18,641 ) 103,680 — (205 ) 84,834 Equity in net (losses)/earnings of affiliates (28,946 ) — (10,923 ) — (39,869 ) 8,693 (2,047 ) (12,861 ) — (6,215 ) Balance Sheet: June 30, 2019 December 31, 2018 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Total assets 2,683,867 1,682,697 263,526 (5,793 ) 4,624,297 2,990,506 1,555,389 266,151 (5,451 ) 4,806,595 Investment in affiliates 259,012 — 263,526 — 522,538 305,631 — 266,151 — 571,782 (1) Eliminations required for consolidation purposes. (2) On March 29, 2019 we signed an agreement with LNG Hrvatska for the future sale of the Golar Viking once converted into an FSRU, following the completion of its current charter lease term, which triggered an impairment indicator. The impairment loss of $34.3 million is recognized in operating costs for the write down of the Golar Viking asset to its fair value. Fair value is based on average broker valuation at date of measurement and represents the exit price in the principal LNG carrier sales market. (3) In May 2019, a major shareholder sold its shareholding which triggered a re-assessment of the carrying value of our investment in OLT-O. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O to its fair value. (4) Inter segment operating income/(loss) relates to management fee revenues and charter revenues between the segments. Revenues from external customers During the six months ended June 30, 2019, our vessels operated predominately under charters within the Cool Pool and tolling fees under our LTA with Perenco and SNH. For the six months ended June 30, 2019 and 2018, revenues from the following customers accounted for over 10% of our total operating revenues, excluding vessel and other management fees: Six months ended June 30, (in thousands of $) 2019 2018 Cool Pool (note 17) 66,691 33 % 83,959 74 % Perenco and SNH 109,048 54 % 18,577 16 %

Revenue

Revenue	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue	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, 2019 24,376 (31,296 ) Payments received for services billed (19,937 ) — Services provided and billed in current period 112,845 — Payments received for services billed in current period (93,475 ) — Deferred commissioning period revenue — 2,110 Closing balance on June 30, 2019 23,809 (29,186 ) (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 ( $3.1 million at December 31, 2018), and • $3.7 million is included in "Amounts due to related parties" under current liabilities ( $4.3 million at December 31, 2018). Refer to note 17 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: Six months ended June 30, (in thousands of $) 2019 2018 Base tolling fee (1) 102,250 17,427 Amortization of deferred commissioning period billing (2) 2,110 357 Amortization of Day 1 gain (3) 4,975 841 Other (287 ) (48 ) Total 109,048 18,577 (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 asset 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.

(Loss)_Earnings Per Share

(Loss)/Earnings Per Share	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
(Loss)/Earnings Per Share	(LOSS)/EARNINGS PER SHARE Basic (loss)/earnings per share ("EPS") is calculated with reference to the weighted average number of common shares outstanding during the period. The components of the numerator for the calculation of basic and diluted EPS are as follows: (in thousands of $) Six months ended June 30, 2019 2018 Net (loss)/income attributable to Golar LNG Limited stockholders - basic and diluted (154,423 ) 15,317 The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) Six months ended June 30, 2019 2018 Basic: Weighted average number of common shares outstanding 100,802 100,628 Dilutive: Dilutive impact of share options — 100 Weighted average number of common shares outstanding 100,802 100,728 (Loss)/earnings per share are as follows: Six months ended June 30, 2019 2018 Basic and diluted $ (1.53 ) $ 0.15 For the six months ended June 30, 2019 and 2018, convertible bonds and employee share plans have been excluded from the calculation of diluted EPS because the effect was anti-dilutive.

Other Financial Items, Net

Other Financial Items, Net	6 Months Ended
	Jun. 30, 2019
Other Income and Expenses [Abstract]
Other Financial Items, Net	OTHER FINANCIAL ITEMS, NET (Losses)/gains on derivative instruments comprise of the following: (in thousands of $) Six months ended June 30, 2019 2018 Mark-to-market adjustment for interest rate swap derivatives (12,226 ) 7,713 Mark-to-market adjustment for equity derivatives (12,605 ) (4,374 ) Interest income on undesignated interest rate swaps 4,093 2,596 Mark-to-market adjustment for foreign exchange swap derivatives 320 (367 ) Unrealized mark-to-market losses on Earn-Out Units — (4,500 ) (20,418 ) 1,068 Other financial items, net comprise of the following: (in thousands of $) Six months ended June 30, 2019 2018 Foreign exchange loss on operations (573 ) (618 ) Amortization of debt guarantee 633 361 Financing arrangement fees and other costs (3,480 ) (53 ) Others 81 (164 ) (3,339 ) (474 )

Operating Lease (Notes)

Operating Lease (Notes)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Operating Leases	8. OPERATING LEASES Rental income The minimum contractual future revenues to be received on non-cancellable time charter leases in respect of our vessels as of June 30, 2019 , were as follows: Period ending December 31, (in thousands of $) 2019 20,079 2020 6,580 Total 26,659 Subsequent to June 30, 2019 , the Golar Artic, Golar Seal, Golar Snow and Golar Ice commenced charters ranging from 8 to 60 months . With the exception of the Hilli which has a carrying value of $1,239.5 million as of June 30, 2019 , management's intention is that all owned vessels are available to be used by customers under operating lease arrangements. The components of operating lease income were as follows: Six months ended June 30, 2019 (in thousands of $) Operating lease income 22,001 Variable lease income (1) 2,698 Total operating lease income 24,699 (1) "Variable lease income" is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases. Rental expense We lease certain office premises, equipment on-board our fleet of vessels and service boats supporting the Hilli under operating leases. Many lease agreements include one or more options to renew. We will include these renewal options when we are reasonably certain that we will exercise the option. The exercise of these lease renewal options is at our discretion. Variable lease cost relates to certain of our lease agreements which include payments that vary. These are primarily generated from service charges related to our usage of office premises, usage charges for equipment on-board our fleet of vessels, adjustments for inflation, and fuel consumption for the rental of service boats supporting the Hilli . The components of operating lease cost were as follows: (in thousands of $) Six months ended June 30, 2019 Operating lease cost (1) 3,430 Variable lease cost (2) 975 Total operating lease cost 4,405 (1) "Operating lease cost" includes short-term lease cost. (2) "Variable lease cost" is excluded from lease payments that comprise the operating lease liability. Total operating lease cost is included in income statement line-items "Vessel operating expenses" and "Administrative expenses". Right-of-use assets obtained in exchange for new operating lease liabilities during the six months ended June 30, 2019 amounted to $12.1 million . Our weighted average remaining lease term for our operating leases is 5.6 years . Our weighted-average discount rate applied for the majority of our operating leases is 5.5% . The maturity of our lease liabilities is as follows: (in thousands of $) Year ending December 31, Operating leases 2019 (1) 2,304 2020 3,452 2021 2,288 2022 1,223 2023 491 Thereafter 2,462 Total operating lease liabilities on June 30, 2019 12,220 (1) For the six months ending December 31, 2019 .
Operating Leases	8. OPERATING LEASES Rental income The minimum contractual future revenues to be received on non-cancellable time charter leases in respect of our vessels as of June 30, 2019 , were as follows: Period ending December 31, (in thousands of $) 2019 20,079 2020 6,580 Total 26,659 Subsequent to June 30, 2019 , the Golar Artic, Golar Seal, Golar Snow and Golar Ice commenced charters ranging from 8 to 60 months . With the exception of the Hilli which has a carrying value of $1,239.5 million as of June 30, 2019 , management's intention is that all owned vessels are available to be used by customers under operating lease arrangements. The components of operating lease income were as follows: Six months ended June 30, 2019 (in thousands of $) Operating lease income 22,001 Variable lease income (1) 2,698 Total operating lease income 24,699 (1) "Variable lease income" is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases. Rental expense We lease certain office premises, equipment on-board our fleet of vessels and service boats supporting the Hilli under operating leases. Many lease agreements include one or more options to renew. We will include these renewal options when we are reasonably certain that we will exercise the option. The exercise of these lease renewal options is at our discretion. Variable lease cost relates to certain of our lease agreements which include payments that vary. These are primarily generated from service charges related to our usage of office premises, usage charges for equipment on-board our fleet of vessels, adjustments for inflation, and fuel consumption for the rental of service boats supporting the Hilli . The components of operating lease cost were as follows: (in thousands of $) Six months ended June 30, 2019 Operating lease cost (1) 3,430 Variable lease cost (2) 975 Total operating lease cost 4,405 (1) "Operating lease cost" includes short-term lease cost. (2) "Variable lease cost" is excluded from lease payments that comprise the operating lease liability. Total operating lease cost is included in income statement line-items "Vessel operating expenses" and "Administrative expenses". Right-of-use assets obtained in exchange for new operating lease liabilities during the six months ended June 30, 2019 amounted to $12.1 million . Our weighted average remaining lease term for our operating leases is 5.6 years . Our weighted-average discount rate applied for the majority of our operating leases is 5.5% . The maturity of our lease liabilities is as follows: (in thousands of $) Year ending December 31, Operating leases 2019 (1) 2,304 2020 3,452 2021 2,288 2022 1,223 2023 491 Thereafter 2,462 Total operating lease liabilities on June 30, 2019 12,220 (1) For the six months ending December 31, 2019 .

Variable Interest Entities ("VI

Variable Interest Entities ("VIE")	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities (VIE)	VARIABLE INTEREST ENTITIES ("VIE") 9.1 Lessor VIEs As of June 30, 2019, we leased eight (December 31, 2018: eight ) vessels from VIEs as part of sale and leaseback agreements, of which four were with ICBCL entities, one with a CMBL entity, one with a CCBFL entity, one with a COSCO Shipping entity and one with a CSSC entity. Each of the ICBCL, CMBL, CCBFL, COSCO Shipping and CSSC entities are wholly-owned, newly formed special purpose vehicles ("Lessor SPVs"). In each of these transactions, we sold our vessel and then subsequently leased back the vessel on a bareboat charter for a term of ten years . We have options to repurchase each vessel at fixed predetermined amounts during their respective charter periods and an obligation to repurchase each vessel at the end of the ten year lease period. Refer to note 5 to our consolidated financial statements filed with our annual report on Form 20-F for the year ended December 31, 2018, for additional details. While we do not hold any equity investments in the above Lessor 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 lessor 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 Lessor SPV. The equity attributable to the respective lessor VIEs are included in non-controlling interests in our consolidated results. As of June 30, 2019 and December 31, 2018, the respective vessels are reported under "Vessels and equipment, net" in our consolidated balance sheets. A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of June 30, 2019, are shown below: (in thousands of $) 2019 (1) 2020 2021 2022 2023 2024+ Golar Glacier 8,620 17,147 17,100 17,100 17,100 12,884 Golar Kelvin 8,620 17,147 17,100 17,100 17,100 15,695 Golar Snow 8,620 17,147 17,100 17,100 17,100 15,695 Golar Ice 8,620 17,147 17,100 17,100 17,100 18,599 Golar Tundra (2) 10,284 19,963 19,196 18,449 17,703 30,527 Golar Seal 6,840 13,717 13,717 13,717 13,754 27,433 Golar Crystal (2) 5,617 11,151 11,066 11,016 10,952 35,092 Hilli (2) 58,322 113,845 109,915 105,984 102,148 389,916 (1) For the six months ending December 31, 2019 . (2) The payment obligations relating to the Golar Tundra , Golar Crystal and Hilli above includes variable rental payments due under the lease based on an assumed LIBOR plus margin. The assets and liabilities of these lessor VIEs that most significantly impact our consolidated balance sheet as of June 30, 2019 and December 31, 2018, are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli June 30, 2019 December 31, 2018 Assets Total Total Restricted cash and short-term deposits 10,652 9 8,707 11,346 — 23,370 4,103 56,789 114,976 176,428 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 146,203 155,626 144,742 120,748 11,065 — 5,748 139,884 724,016 646,513 Long-term interest bearing debt - non-current portion (1) — — — — 102,256 123,105 88,036 718,800 1,032,197 1,200,774 146,203 155,626 144,742 120,748 113,321 123,105 93,784 858,684 1,756,213 1,847,287 (1) Where applicable, these balances are net of deferred finance charges. The most significant impact of lessor VIE's operations on our unaudited consolidated statements of income is interest expense of $35.9 million and $19.1 million for the six months ended June 30, 2019 and 2018, respectively. The most significant impact of lessor VIE's cash flows on our unaudited consolidated statements of cash flows is receipts of $91.6 million and $864.7 million in financing activities for the six months ended June 30, 2019 and 2018, respectively. 9.2 Golar Hilli LLC Following to the sale of common units in Golar Hilli LLC, 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 has concluded that Hilli LLC is a VIE and that we are the primary beneficiary. Summarized financial information of Hilli LLC The assets and liabilities of Hilli LLC (1) that most significantly impact our consolidated balance sheet are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Balance sheet Current assets 112,646 172,554 Non-current assets 1,366,869 1,392,713 Current liabilities (200,633 ) (278,728 ) Non-current liabilities (805,686 ) (842,786 ) (1) 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 unaudited consolidated statements of income, and unaudited consolidated statements of cash flows, are as follows: (in thousands of $) Six months ended June 30, 2019 Six months ended June 30, 2018 Statement of operations Liquefaction services revenue 109,048 18,577 Realized and unrealized gains on the oil derivative instrument 8,145 111,348 Statement of cash flows Net debt repayments 39,297 — Net debt receipts — 928,280 9.3 Gimi MS On April 16, 2019, the subscription of 30% of the equity interests in Gimi MS by First FLNG Holdings was completed. Concurrent with the closing of the sale of the common units, we have determined that (i) Gimi MS is a VIE, (ii) we are the primary beneficiary and retain sole control over the most significant activities and the greatest exposure to variability in residual returns and expected losses from the Gimi . Thus Gimi MS continues to be consolidated into our financial statements. Summarized financial information of Gimi MS The assets and liabilities of Gimi MS that most significantly impact our consolidated balance sheet are as follows: (in thousands of $) June 30, 2019 Balance sheet Current assets 48,328 Non-current assets 187,056 Current liabilities (40,837 ) The most significant impact of Gimi MS VIE's operations on our unaudited consolidated statements of cash flows, are as follows: (in thousands of $) Six months ended June 30, 2019 Statement of cash flows Additions to asset under development 105,339

Restricted Cash and Short Term

Restricted Cash and Short Term Deposits	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Restricted Cash and Short-Term Deposits	RESTRICTED CASH AND SHORT-TERM DEPOSITS Our restricted cash and short-term deposits balances are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Restricted cash relating to the total return equity swap 96,763 82,863 Restricted cash in relation to the Hilli 151,957 174,597 Restricted cash and short-term deposits held by lessor VIEs 114,976 176,428 Collateral on the Margin Loan Facility 33,413 33,413 Restricted cash relating to the $1.125 billion debt facility 7,648 17,657 Restricted cash relating to office lease 786 777 Bank guarantee 43 691 Total restricted cash and short-term deposits 405,586 486,426 Less: Amounts included in current restricted cash and short-term deposits (252,843 ) (332,033 ) Long-term restricted cash 152,743 154,393

Asset Under Development

Asset Under Development	6 Months Ended
	Jun. 30, 2019
Extractive Industries [Abstract]
Asset Under Development	ASSET UNDER DEVELOPMENT (in thousands of $) June 30, 2019 Opening asset under development balance 20,000 Transfer from other non-current assets (note 13) 31,048 Additions 127,444 Interest costs capitalized 1,888 Other costs capitalized 6,580 Closing asset under development balance 186,960 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, the 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. Various preparatory work on the Gimi conversion continues with the first steel being cut in April 2019 and the overall project remains on track and the charter is expected to commence in 2022. In April 2019, we issued the shipyard with a Final Notice to Proceed with conversion works that had been initiated under the Limited Notice to Proceed. The estimated conversion cost of the Gimi is approximately $1.3 billion . As at June 30, 2019, the estimated timing of the outstanding payments in connection with the Gimi conversion are as follows: Period ending December 31, (in thousands of $) June 30, 2019 2019 (1) 235,923 2020 364,748 2021 213,203 2022 230,724 2023 134,231 1,178,829 (1) For the six months ending December 31, 2019 $700 million facility On April 16, 2019, we received a $700 million underwritten financing commitment for a long-term financing facility, which is subject to the satisfaction of certain conditions by the parties and final documentation. The facility will be available during the Gimi conversion and has a tenure of 7 years post commissioning and a 12 -year amortization profile. Drawdown from the facility is dependent upon reaching project spend of $300 million . Concurrent with receipt of this financing commitment, First FLNG Holdings, an indirect wholly-owned subsidiary of Keppel Capital Holdings Pte Ltd, subscribed to 30% of the total issued ordinary share capital of Gimi MS.

Investments in Affiliates and J

Investments in Affiliates and Joint Ventures	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Investments in Affiliates and Joint Ventures	INVESTMENTS IN AFFILIATES AND JOINT VENTURES Six months ended June 30, (in thousands of $) 2019 2018 Share of net (losses)/earnings in Golar Partners (27,659 ) 8,630 Share of net loss in Golar Power (10,923 ) (12,861 ) Share of net loss in OneLNG — (2,047 ) Share of net (losses)/earnings in others (858 ) 63 Share of net loss in Avenir (429 ) — (39,869 ) (6,215 ) The carrying amounts of our investments in our equity method investments as at June 30, 2019 and December 31, 2018 are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Golar Partners 225,094 271,160 Golar Power 263,526 266,151 Avenir 28,927 28,710 Others 4,991 5,761 Equity in net assets of affiliates 522,538 571,782

Other Non-Current Assets

Other Non-Current Assets	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS Other non-current assets comprise of the following: (in thousands of $) June 30, 2019 December 31, 2018 Oil derivative instrument (1) 85,572 84,730 Operating lease right-of-use-assets (2) 12,093 — Investment in OLT-O (3) — 7,347 Other non-current assets (4) 18,780 40,729 Mark-to-market interest rate swaps valuation 218 6,298 116,663 139,104 (1) "Oil derivative instrument" refers to a derivative embedded in the Hilli LTA. See note 2 for further details. (2) Following the adoption of ASC 842, the balance sheet presents right-of-use-assets which mainly comprise of our office leases. This standard has been adopted under a modified retrospective transition approach as of January 1, 2019 . (3) Investment in 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, representing a 2.7% interest in OLT-O’s issued share capital. In May 2019 , a major shareholder sold its shareholding which triggered a re-assessment of the carrying value of our investment in OLT-O. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O. (4) "Other non-current assets" as of June 30, 2019 includes payments made for long lead items ordered in preparation for the conversion of the Viking into an FSRU. As of June 30, 2019 the aggregate carrying value of Viking long lead items was $9.1 million . "Other non-current assets" as of December 31, 2018 was mainly comprised of payments made relating to long lead items ordered in preparation for the conversion of the Gimi into a FLNG vessel. Subsequent to the receipt of a Limited Notice to Proceed from BP in relation to the Greater Tortue in December 2018 , initial works of the FLNG conversion commenced in January 2019 . Consequently, as of June 30, 2019 , the aggregate carrying value of $31.0 million has been reclassified to "Asset under development" (see note 11).

Debt

Debt	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Debt	DEBT As of June 30, 2019 , and December 31, 2018 , our debt was as follows: (in thousands of $) June 30, 2019 December 31, 2018 Golar Arctic facility 54,650 58,300 Golar Viking facility 44,271 46,875 2017 convertible bonds 360,665 353,661 Margin loan 100,000 100,000 $1.125 billion facility 162,873 173,732 Subtotal (excluding lessor VIE loans) 722,459 732,568 ICBCL VIE loans (1) 568,608 609,220 CCBFL VIE loan (1) 123,105 123,524 CMBL VIE loan (1) 113,321 121,741 COSCO Shipping VIE loan (1) 94,351 97,163 CSSC VIE loan (1) 858,684 897,980 Total debt 2,480,528 2,582,196 Less: Deferred finance charges, net (13,020 ) (16,837 ) Total debt, net of deferred financing costs 2,467,508 2,565,359 At June 30, 2019 , our debt, net of deferred financing costs, is broken down as follows: Golar debt VIE debt (1) Total debt (in thousands of $) Current portion of long-term debt and short-term debt 78,307 724,016 802,323 Long-term debt 632,988 1,032,197 1,665,185 Total 711,295 1,756,213 2,467,508 (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 9).

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	6 Months Ended
	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Loss	ACCUMULATED OTHER COMPREHENSIVE LOSS The components of accumulated other comprehensive loss consisted of the following: (in thousands of $) Pension and post-retirement benefit plan adjustments Share of affiliates' comprehensive income Total accumulated comprehensive loss Balance at December 31, 2017 (12,799 ) 5,030 (7,769 ) Other comprehensive loss — (24,137 ) (24,137 ) Balance at June 30, 2018 (12,799 ) (19,107 ) (31,906 ) Balance at December 31, 2018 (9,218 ) (19,294 ) (28,512 ) Other comprehensive income — 651 651 Balance at June 30, 2019 (9,218 ) (18,643 ) (27,861 )

Financial Instruments

Financial Instruments	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Financial Instruments	FINANCIAL INSTRUMENTS Fair values We recognize our fair value estimates using a fair value hierarchy based on the inputs used to measure fair value. The fair value of 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. Level 3: Unobservable inputs that are not corroborated by market data. The carrying values and estimated fair values of our financial instruments at June 30, 2019 and December 31, 2018 are as follows: June 30, 2019 December 31, 2018 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents Level 1 139,834 139,834 217,835 217,835 Restricted cash and short-term deposits Level 1 405,586 405,586 486,426 486,426 Current portion of long-term debt and short-term debt (1)(2) Level 2 (806,999 ) (906,999 ) (732,184 ) (732,184 ) Long-term debt - convertible bonds (2) Level 2 (360,665 ) (372,651 ) (353,661 ) (373,029 ) Long-term debt (2) Level 2 (1,312,864 ) (1,212,864 ) (1,496,351 ) (1,496,351 ) Derivatives: Oil derivative instrument (3)(6) Level 2 85,572 85,572 84,730 84,730 Interest rate swaps asset (3)(4) Level 2 1,928 1,928 10,770 10,770 Interest rate swaps liability (3)(4) Level 2 (3,384 ) (3,384 ) — — Foreign exchange swaps asset (3) Level 2 92 92 — — Foreign exchange swaps liability (3) Level 2 (1,094 ) (1,094 ) (1,322 ) (1,322 ) Total return equity swap liability (3)(4)(5) Level 2 (83,410 ) (83,410 ) (70,804 ) (70,804 ) (1) The carrying amounts of our short-term debt 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 above are gross of the deferred finance charges amounting to $ 13.0 million and $ 16.8 million at June 30, 2019 and December 31, 2018 , respectively. (3) Derivative liabilities are captured within other current liabilities and derivative assets are generally captured within other current assets and non-current assets on the balance sheet. (4) 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. (5) 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. (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 and short-term oil prices obtained from quoted prices in active markets. As of June 30, 2019 , 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 $) Notional value Maturity dates Fixed interest rates Interest rate swaps: Receiving floating, pay fixed 950,000 2019 to 2025 1.28% to 2.37% During the six months ended June 30, 2019 , we entered into new interest rate swaps with a notional value of $250.0 million and terminated existing interest rate swaps with a notional value of $250.0 million . The credit exposure of our interest rate and equity swap agreements are represented by the fair value of contracts with a positive fair value at the end of each period, reduced by the effects of master netting agreements. It is our policy to enter into master netting agreements with the counterparties to derivative financial instrument contracts, which give us the legal right to discharge all or a portion of amounts owed to the counterparty by offsetting them against amounts that the counterparty owes to us. 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 June 30, 2019 and December 31, 2018 would be adjusted as detailed in the following table: June 30, 2019 December 31, 2018 (in thousands of $) 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 Total asset derivatives 1,928 (917 ) 1,011 10,770 — 10,770 Total liability derivatives (3,384 ) 917 (2,467 ) — — — The total return equity swap has a credit arrangement that requires us to provide cash collateral equalling 20% of the initial purchase price and to subsequently post additional cash collateral that corresponds to any unrealized loss. As at June 30, 2019 , cash collateral amounting to $96.8 million

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS a) Transactions with Golar Partners and subsidiaries: Net revenues (expenses): The transactions with Golar Partners and its subsidiaries for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue (a) 4,747 3,877 Ship management fees revenue (b) 2,230 2,600 Interest expense on deposits payable (c) — (4,484 ) Total 6,977 1,993 Payables: The balances with Golar Partners and its subsidiaries as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances owing to Golar Partners and affiliates (d) 247 4,091 Methane Princess lease security deposit movement (e) (2,383 ) (2,835 ) Total (2,136 ) 1,256 a) Management and administrative services agreement - On March 30, 2011, Golar Partners entered into a management and administrative services agreement with Golar Management Limited ("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. b) 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. c) Interest expense on deposits payable 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 in return we were 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 was applied to the net sale price of the Hilli Disposal (defined below) on July 12, 2018 . Deposit received from Golar Partners - On August 15, 2017, we entered into the Hilli Sale Agreement with Golar Partners for the Hilli, or the Hilli Disposal, from the Sellers of the Hilli Common Units in Hilli LLC. On the Closing Date of the Hilli Disposal, Hilli LLC will 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 Perenco and SNH under an eight -year LTA. Concurrent 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 applied the deposit received and interest accrued to the purchase price on July 12, 2018, upon completion of the Hilli Disposal. We have accounted for $ nil and $2.7 million , and $ nil and $1.8 million from the above arrangements as interest expense on the Deferred Purchase Price and the $70 million deposit for the six months ended June 30, 2019 and 2018 , respectively. d) Trading balances - Receivables and payables with Golar Partners and its subsidiaries are comprised primarily of unpaid management fees, interest expense and expenses for management, advisory and administrative services and may include working capital adjustments with respect to 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. e) 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 the Methane Princess Lease. 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. Other transactions: During the six months ended June 30, 2019 and 2018, we received total distributions from Golar Partners of $18.3 million and $26.2 million , respectively with respect to the common units and general partner units owned by us. During the six months ended June 30, 2019 , Hilli LLC had declared distributions totalling $9.0 million with respect to the common units owned by Golar Partners. In connection with the Hilli Disposal we have agreed to indemnify Golar Partners for certain costs incurred in Hilli operations when these costs exceed a contractual ceiling. We have accounted for $0.8 million as the net Hilli indemnification cost for the six months ended June 30, 2019 . As of June 30, 2019 , we have a payable of $6.8 million to Golar Partners, recorded in "amounts due to related parties", in respect of the Hilli quarterly distribution and Hilli cost indemnification. b) Transactions with Golar Power and affiliates: Net revenues: The transactions with Golar Power and its affiliates for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue 3,011 2,457 Ship management fees income 606 700 Debt guarantee compensation (a) 633 361 Other — (247 ) Total 4,250 3,271 Payables: The balances with Golar Power and its affiliates as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances due to Golar Power and affiliates (b) (2,583 ) (5,417 ) Total (2,583 ) (5,417 ) a) Debt guarantee compensation - In connection with the closing of the formation of the joint venture Golar Power with Stonepeak, Golar Power entered into agreements to compensate Golar in relation to certain debt guarantees relating to Golar Power and its subsidiaries. This compensation amounted to an aggregate of $0.6 million and $0.4 million income for the six months ended June 30, 2019 and 2018 , respectively. b) Trading balances - Receivables and payables with Golar Power and its subsidiaries are comprised primarily of unpaid management fees, charterhire expenses, advisory and administrative services and may include working capital adjustments in connection with the initial formation of the joint venture and transaction with Stonepeak. 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. They primarily relate to recharges for trading expenses paid on behalf of Golar Power, including ship management and administrative service fees due to us. Guarantees: 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 (a) 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 June 30, 2019 and December 31, 2018 , the Company guaranteed $376.8 million and $393.5 million , respectively of Golar Power's gross long-term debt obligations. The debt facilities are secured against specific vessels. c) Transactions with OneLNG and subsidiaries: Net revenues: The transactions with OneLNG and its subsidiaries for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue — 1,399 Total — 1,399 Receivables: The balances with OneLNG and its subsidiaries as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances due from OneLNG (a) 5,207 8,169 Total 5,207 8,169 a) Trading balances - Receivables and payables with One LNG and its subsidiaries are comprised primarily of unpaid management fees, charterhire expenses, advisory, administrative services and payment on behalf of a related party and vice versa. In 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. During the six months ended June 30, 2019 , we have written off $3.0 million of the unrecoverable trading balance with OneLNG. d) Transactions with the Cool Pool: The table below summarizes our earnings generated from our participation in the Cool Pool: Six Months Ended (in thousands of $) 2019 2018 Time and voyage charter revenues 43,332 64,605 Time charter revenues - collaborative arrangement 23,359 19,353 Voyage, charterhire and commission expenses (8,092 ) (8,600 ) Voyage, charterhire and commission expenses - collaborative arrangement (18,933 ) (30,897 ) Net income from the Cool Pool 39,666 44,461 Receivables from other related parties: (in thousands of $) June 30, 2019 December 31, 2018 Cool Pool 11,205 43,985 11,205 43,985

Other Commitments and Contingen

Other Commitments and Contingencies	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Other Commitments and Contingencies	OTHER COMMITMENTS AND CONTINGENCIES Assets pledged (in thousands of $) June 30, 2019 December 31, 2018 Book value of vessels secured against long-term loans 3,165,857 3,244,291 As at June 30, 2019 and December 31, 2018 , 21,226,586 Golar Partners common units were pledged as security for the obligations under the Margin Loan Facility. Capital Commitments We have agreed contract terms for the conversion of the Gandria to a FLNG. The Gandria is currently in lay-up awaiting delivery to Keppel for conversion. The conversion agreement is subject to certain payments and lodging of a full Notice to Proceed. UK tax lease benefits As described under note 30 in our audited consolidated financial statements filed with our annual report on Form 20-F for the year ended December 31, 2018 , 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 (before deduction of fees). Of these six leases, we have since terminated five , with one lease remaining, 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 June 30, 2019 , 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 had the election to appeal the courts’ decision, but no appeal was 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. HMRC have written to our lessor to indicate that they believe our lease may be similar to the case noted above, however we remain confident that our fact pattern is sufficiently different. 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 £115.0 million . We continue to have discussions with HMRC on this matter, although we deem it unlikely that the inquiry will be brought to a mutually satisfactory conclusion. Accordingly, we are determining how best to proceed in conjunction with our lessor. This will likely involve obtaining supplementary legal advice in addition to the advice we have previously received. We remain confident of our legal position, however given the complexity of these discussions it is impossible to quantify the reasonably possible loss, and 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 June 30, 2019 , 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. 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 around €1.0 million . In the event a positive FID is taken on the project, this could increase up to approximately €15.0 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. For the period ended June 30, 2019 we recovered $9.3 million , which represents the last installment settlement, recognized in 'Other operating income' in the unaudited consolidated statements of operations. In relation to our investment in small-scale LNG services provider Avenir LNG Limited ("Avenir") (see note 12), we are party to a combined commitment of up to $182.0 million from initial Avenir shareholders Stolt-Nielsen Limited ("Stolt-Nielsen"), Höegh LNG Holdings Limited ("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 $18.0 million . Following the execution of the conversion and subsequent sale of the Golar Viking with LNG Hrvatska d.o.o., the estimated timing of the outstanding payments in connection with the conversion of the Golar Viking is $8.7 million and $86.7 million for the six months ending December 31, 2019 and twelve months ending December 2020 . The outstanding payment will be largely funded by stage payments from LNG Hrvatska d.o.o. under the conversion agreement.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2019
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Margin loan refinancing In August 2019, we entered into an agreement with a group of lenders to refinance our existing Margin Loan Facility. The new Margin Loan Facility introduces a revolving element, increases the principal amount available to draw to $110 million and has a maturity of one year from execution. The new Margin Loan Facility will continue to be secured by a pledge against our common units in Golar Partners. $150 million term loan facility In August 2019, we entered into a $150 million term loan facility with a total term of fifteen months .

Accounting Policies (Policies)

Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Basis of accounting	The condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States ("U.S. GAAP"). The condensed consolidated financial statements do not include all of the disclosures required under U.S. GAAP in the annual consolidated financial statements, and should be read in conjunction with our audited annual financial statements for the year ended December 31, 2018, which are included in our annual report on Form 20-F.
Lessee, leases	Contracts relating to our LNG carriers, FSRUs and FLNG asset can take the form of operating leases, finance leases, tolling agreements and management agreements. In addition, we contract a portion of our vessels in the spot market through our collaborative arrangement, the "Cool Pool". Although the substance of these contracts are similar, (they allow our customers to hire our assets and to avail of Golar's management services for a specified day rate) the accounting treatment varies. We outline our policies for determining the appropriate GAAP treatment below. Lease accounting versus revenue accounting To determine whether a contract conveys a lease agreement for a period of time, the Group has assessed whether, throughout the period of use, the customer has both of the following: • the right to obtain substantially all of the economic benefits from the use of the identified asset; and • the right to direct the use of that identified asset. If a contract relating to an asset fails to give the customer both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e. another third party could contract for a meaningful amount of the asset capacity). In situations where we provide management services unrelated to an asset contract, we account for the contract as a revenue contract. Lease accounting When a contract is designated as a lease, we make an assessment on whether the contract is an operating lease or a finance lease. An agreement will be a finance lease if any of the following conditions are met: • ownership of the asset is transferred at the end of the lease term; • the contract contains an option to purchase the asset which is reasonably certain to be exercised; • the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the asset's useful life are not subject to this criterion; • the discounted value of the fixed payments under the lease represent substantially all of the fair value of the asset; or • the asset is heavily customized such that it could not be used for another charter at the end of the term.
Lessor, leases	Contracts relating to our LNG carriers, FSRUs and FLNG asset can take the form of operating leases, finance leases, tolling agreements and management agreements. In addition, we contract a portion of our vessels in the spot market through our collaborative arrangement, the "Cool Pool". Although the substance of these contracts are similar, (they allow our customers to hire our assets and to avail of Golar's management services for a specified day rate) the accounting treatment varies. We outline our policies for determining the appropriate GAAP treatment below. Lease accounting versus revenue accounting To determine whether a contract conveys a lease agreement for a period of time, the Group has assessed whether, throughout the period of use, the customer has both of the following: • the right to obtain substantially all of the economic benefits from the use of the identified asset; and • the right to direct the use of that identified asset. If a contract relating to an asset fails to give the customer both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e. another third party could contract for a meaningful amount of the asset capacity). In situations where we provide management services unrelated to an asset contract, we account for the contract as a revenue contract. Lease accounting When a contract is designated as a lease, we make an assessment on whether the contract is an operating lease or a finance lease. An agreement will be a finance lease if any of the following conditions are met: • ownership of the asset is transferred at the end of the lease term; • the contract contains an option to purchase the asset which is reasonably certain to be exercised; • the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the asset's useful life are not subject to this criterion; • the discounted value of the fixed payments under the lease represent substantially all of the fair value of the asset; or • the asset is heavily customized such that it could not be used for another charter at the end of the term. Lessor accounting In making the classification assessment, we estimate the residual value of the underlying asset at the end of the lease term with reference to broker valuations. None of our lease contracts contain residual value guarantees and any purchase options are disclosed in note 9. Agreements which include renewal and termination options are included in the lease term if we believe they are "reasonably certain" to be exercised by the lessee or if controlled by the lessor. The determination of whether lessee extension clauses are reasonably certain depends whether the option contains an economic incentive. Generally, lease accounting commences when the asset is made available to the customer, however, where the contract contains specific customer acceptance testing conditions, lease accounting will not commence until the asset has successfully passed the acceptance test. We assess a lease under the modification guidance when there is a change to the terms and conditions of the contract that results in a change in the scope or the consideration of the lease. Costs directly associated with the execution of the lease or costs incurred after lease inception (the execution of the contract) but prior to the commencement of the lease that directly relate to preparing the asset for the contract (for example bunker costs), are capitalized and amortized to the consolidated statement of income over the lease term. We also defer upfront revenue payments (for example positioning fees) to the consolidated balance sheet and amortize to the consolidated statement of income over the lease term. Fixed revenue from operating leases is accounted for on a straight line basis over the life of the lease; while variable revenue is accounted for as incurred in the relevant period. Fixed revenue includes fixed payments and variable payments based on a rate or index. For our operating leases, we have elected the practical expedient to combine our service revenue and operating lease income as both the timing and the pattern of transfer of the components are the same. On inception of a finance lease, we derecognize the related asset and record a "net investment in finance lease" financial asset on our consolidated balance sheet. The net investment represents the fixed payments due from the lessee and unguaranteed residual value, discounted at the discount rate implicit in the lease. We recognize finance lease income in the consolidated statement of income (“interest income”) to reflect the implicit rate of interest applied to the outstanding financial asset balance.
Revenue accounting	Contracts within the scope of revenue accounting include our liquefaction services contract relating to the Hilli asset and our management fee services provided to our affiliates (Golar Partners and Golar Power) and customers who lease our assets under finance lease arrangements. For liquefaction services revenue, the provision of liquefaction services capacity is considered a single performance obligation recognised evenly over time. We consider our services (the receipt of customer's gas, treatment and temporary storage on board our FLNG and delivery of LNG to waiting carriers) to be a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. 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. Contractual payment terms for liquefaction services is monthly in arrears. Contract liabilities arise when the customer makes payments in advance of receiving services. The period between when invoicing and when payment is due is not significant. Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. The management services we provide 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. 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 that we have the right to invoice. Our contracts generally have an initial term of one year or less, after which the arrangement continues with a short notice period until the end of the contract, ranging from 30 days to 180 days. Contract assets arise when we render management services in advance of receiving payment from our customers.
Derivatives	Changes in presentation of fair value of derivative instruments and oil derivative instrument Effective from the quarter ended September 30, 2018, we presented two new line items in operating activities on the face of the statements of cash flows. Given the significance of the oil derivative instrument in the current year, we believe that the introduction of this new line item in the statements of cash flows provides users of our financial statements with 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 period ended June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted Change in fair value of derivative instruments — 1,528 1,528 Change in fair value of oil derivative instrument — (108,300 ) (108,300 ) Change in assets and liabilities: Other current and non-current assets (105,056 ) 111,499 6,443 Other current and non-current liabilities 43,764 (4,727 ) 39,037 Gains/(losses) on derivative instruments Effective from the quarter ended September 30, 2018, we presented a new line item under financial income/(expense) on the face of the statements of income. The new line item, "Losses 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 these new line items will provide users of our financial statements with greater transparency over our derivative instruments. This presentation change has been retrospectively applied for all prior periods. The change in presentation for the six months ended June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments Increase/ (Decrease) As adjusted Gains on derivative instruments — 1,068 1,068 Other financial items, net 594 (1,068 ) (474 ) Oil Derivative Instrument In relation to the oil derivative instrument, 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 Liquefication 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 necessary to blend the long and 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 within "Realized and unrealized gain on oil derivative instrument" as part of the consolidated statement of income. The realized and unrealized gain on oil derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2019 2018 Realized gain on oil derivative instrument 7,395 3,048 Unrealized gain on oil derivative instrument 750 108,300 8,145 111,348 For further information on the nature of this derivative, refer to note 16. The unrealized gain results from movement in oil prices above a contractual floor price over term of the LTA; whereas the realized gain results from monthly billings above the base tolling fee under the LTA.
Impairment of non-current assets	In March 2019, we entered into a number of contracts relating to the conversion and subsequent disposal of the Golar Viking. As of March 31, 2019, although we were still awaiting on LNG Hrvatska to issue Golar a final notice to proceed, we determined that there was sufficient probability of the sale being finalized to trigger an impairment test on the vessel. The impairment test resulted in a charge of $34.3 million . The fair value of the LNG carrier Golar Viking is categorized within level 2 of the fair value hierarchy, and is based on the average of third party broker valuations. The fair value does not factor in any cash flows associated with the conversion project. The value represents the price that a market participant would pay for a LNG carrier as this is the principal market for the vessel. This is consistent with the fair value methodology that we use for all of our LNG carriers. In May 2019, a major shareholder of OLT Offshore LNG Toscana S.P.A. (OLT-O) sold its shareholdings which triggered a re-assessment of the carrying value of our investment in OLT-O that was previously recorded at a measurement alternative of cost less impairment as no readily determinable fair value was available. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O to its fair value.
Use of estimates	The preparation of financial statements in accordance with United States Generally Accepted Accounting Principles ("U.S. 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 June 30, 2019, we leased eight vessels under finance leases 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 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.
Adoption of new accounting standards and Accounting pronouncments that have been issued but not adopted	Adoption of new accounting standards In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) along with subsequent amendments ASU 2019-20 Leases (Topic 842): Narrow scope improvements for lessors in December 2018 and ASU 2019-01 Leases (Topic 842): Codification improvements in March 2019. Topic 842 modifies the definition of a lease, requires reassessment of the lease term upon the occurrence of certain triggers and introduces new disclosures. Lessors are required to classify leases as sales-type, direct financing or operating, with classification affecting the pattern of income recognition and provide 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. We adopted this Topic 842 on January 1, 2019 under a modified retrospective transition approach. In contracts where we act as either the lessor or lessee, we have elected to use the "package" of practical expedients available, which means no reassessment on transition of whether an agreement contains a lease, lease classification, and initial direct costs under ASC 842. As part of this package the lease term has been determined using hindsight up to the date of transition when considering lessee options to extend or terminate the agreement or to purchase the underlying asset. Furthermore, where available we have elected not to separate the components in our lease arrangements, instead accounting for them on a combined component basis under ASC 842. 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. The impact on the Company of applying ASU 842 as a lessee, based on contractual arrangements in place at December 31, 2018, was the recognition of lease liabilities of $15.8 million , along with right-of-use assets with a similar aggregate value, which mainly relates to our office leases. This liability corresponds to our lessee related liability for future lease payments presented on the face of the consolidated balance sheet as other current liabilities of $5.5 million and other non-current liabilities of $10.3 million , while the carrying value of the lessee right-of-use assets is disclosed in note 13 to these condensed consolidated financial statements. For contracts where we are the lessor, the practical expedients that we have elected has resulted 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 have been assessed under the requirements of Topic 842. New lessor presentation and disclosure requirements have been applied to our new and existing lease agreements. The carrying value of the assets subject to lessor operating leases, and the maturity analysis of operating lease payments under arrangements where we are the lessor, are disclosed in note 8 to the condensed consolidated financial statements. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics including primarily minor corrections, clarifications and codification improvements. We adopted the codification improvements that were not effective on issuance on January 1, 2019 under the specified transition approach connected with each of the codification improvements. This amendment has not had a material impact on our consolidated financial statements or related disclosures, including retained earnings, as January 1, 2019. Accounting pronouncements that have been issued but not adopted The following table provides a brief description of recent accounting standards that have been issued but not yet adopted: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and subsequent amendments, including ASU 2018-19 & ASU 2019-04 Codification Improvements to Topic 326 ‘‘Financial Instruments-Credit Losses” Replaces the incurred loss impairment methodology with an expected loss methodology that requires a consideration of a broader range of reasonable and supportable information to inform credit loss estimates. January 1, 2020 Under evaluation ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement Removes some disclosure requirements relating to transfers between Level 1 and Level 2 of the FV hierarchy. Introduces new disclosure requirements for Level 3 measurements January 1, 2020 No material impact on our disclosure requirements as we have no Level 3 measurements. ASU 2018-14 Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans . Removes some disclosure requirements that are not expected to materially change Golar’s existing note. Introduces new disclosure requirements including an explanation of the reasons for significant gains and losses relating to changes in the benefit obligation. January 1, 2021 No material impact on disclosure requirements. 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 . Aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal use software. January 1, 2020 No material impact on disclosure requirements. ASU 2018-17 Consolidation (Topic 810) - Targeted Improvements to Related Party Guidance for Variable Interest Entities For the purposes of determining whether a decision making fee is a variable interest, a company is now required to consider indirect interests held through related parties under common control on a proportionate basis as opposed to as a direct investment in the entity. January 1, 2020 No impact on historical consolidation assessments. ASU 2018-18 Collaborative Arrangements (Topic 808) - Clarifying the Interaction between Topic 808 and Topic 606 . Provides guidance on determining when transactions between collaborative arrangement participants should be accounted for as revenue under 606. January 1, 2020 Under evaluation

Accounting Policies (Tables)

Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Schedule of Error Corrections and Prior Period Adjustments	The change in presentation for the period ended June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments (decrease) increase As adjusted Change in fair value of derivative instruments — 1,528 1,528 Change in fair value of oil derivative instrument — (108,300 ) (108,300 ) Change in assets and liabilities: Other current and non-current assets (105,056 ) 111,499 6,443 Other current and non-current liabilities 43,764 (4,727 ) 39,037 June 30, 2018 is as follows: Six Months Ended June 30, 2018 (in thousands of $) As previously reported Adjustments Increase/ (Decrease) As adjusted Gains on derivative instruments — 1,068 1,068 Other financial items, net 594 (1,068 ) (474 )
Schedule of Price Risk Derivatives	The realized and unrealized gain on oil derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2019 2018 Realized gain on oil derivative instrument 7,395 3,048 Unrealized gain on oil derivative instrument 750 108,300 8,145 111,348

Recently Issued Accounting St_2

Recently Issued Accounting Standards Recently Issued Accounting Standards (Tables)	6 Months Ended
	Jun. 30, 2019
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The following table provides a brief description of recent accounting standards that have been issued but not yet adopted: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and subsequent amendments, including ASU 2018-19 & ASU 2019-04 Codification Improvements to Topic 326 ‘‘Financial Instruments-Credit Losses” Replaces the incurred loss impairment methodology with an expected loss methodology that requires a consideration of a broader range of reasonable and supportable information to inform credit loss estimates. January 1, 2020 Under evaluation ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement Removes some disclosure requirements relating to transfers between Level 1 and Level 2 of the FV hierarchy. Introduces new disclosure requirements for Level 3 measurements January 1, 2020 No material impact on our disclosure requirements as we have no Level 3 measurements. ASU 2018-14 Compensation-Retirement Benefits-Defined Benefit Plans-General (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans . Removes some disclosure requirements that are not expected to materially change Golar’s existing note. Introduces new disclosure requirements including an explanation of the reasons for significant gains and losses relating to changes in the benefit obligation. January 1, 2021 No material impact on disclosure requirements. 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 . Aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal use software. January 1, 2020 No material impact on disclosure requirements. ASU 2018-17 Consolidation (Topic 810) - Targeted Improvements to Related Party Guidance for Variable Interest Entities For the purposes of determining whether a decision making fee is a variable interest, a company is now required to consider indirect interests held through related parties under common control on a proportionate basis as opposed to as a direct investment in the entity. January 1, 2020 No impact on historical consolidation assessments. ASU 2018-18 Collaborative Arrangements (Topic 808) - Clarifying the Interaction between Topic 808 and Topic 606 . Provides guidance on determining when transactions between collaborative arrangement participants should be accounted for as revenue under 606. January 1, 2020 Under evaluation

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Six Months Ended June 30, 2019 Six Months Ended June 30, 2018 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 101,984 109,048 — — 211,032 106,987 18,577 — — 125,564 Depreciation and amortization (32,182 ) (24,102 ) — — (56,284 ) (32,775 ) (4,091 ) — — (36,866 ) Other operating expenses (93,305 ) (28,860 ) — — (122,165 ) (103,058 ) (12,172 ) — — (115,230 ) Impairment of long-term assets (2) (3) (41,597 ) — — — (41,597 ) — — — — — Other operating gains (note 18) 9,260 5,183 — — 14,443 10,000 101,366 — — 111,366 Operating (loss)/income (55,840 ) 61,269 — — 5,429 (18,846 ) 103,680 — — 84,834 Inter segment operating income/(loss) (4) 342 — — (342 ) — 205 — — (205 ) — Segment operating/(loss) income (55,498 ) 61,269 — (342 ) 5,429 (18,641 ) 103,680 — (205 ) 84,834 Equity in net (losses)/earnings of affiliates (28,946 ) — (10,923 ) — (39,869 ) 8,693 (2,047 ) (12,861 ) — (6,215 ) Balance Sheet: June 30, 2019 December 31, 2018 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Total assets 2,683,867 1,682,697 263,526 (5,793 ) 4,624,297 2,990,506 1,555,389 266,151 (5,451 ) 4,806,595 Investment in affiliates 259,012 — 263,526 — 522,538 305,631 — 266,151 — 571,782 (1) Eliminations required for consolidation purposes. (2) On March 29, 2019 we signed an agreement with LNG Hrvatska for the future sale of the Golar Viking once converted into an FSRU, following the completion of its current charter lease term, which triggered an impairment indicator. The impairment loss of $34.3 million is recognized in operating costs for the write down of the Golar Viking asset to its fair value. Fair value is based on average broker valuation at date of measurement and represents the exit price in the principal LNG carrier sales market. (3) In May 2019, a major shareholder sold its shareholding which triggered a re-assessment of the carrying value of our investment in OLT-O. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O to its fair value. (4) Inter segment operating income/(loss) relates to management fee revenues and charter revenues between the segments.
Schedules of Concentration of Risk, by Risk Factor	For the six months ended June 30, 2019 and 2018, revenues from the following customers accounted for over 10% of our total operating revenues, excluding vessel and other management fees: Six months ended June 30, (in thousands of $) 2019 2018 Cool Pool (note 17) 66,691 33 % 83,959 74 % Perenco and SNH 109,048 54 % 18,577 16 %

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Change in Contract with Customer, Asset and Liability	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, 2019 24,376 (31,296 ) Payments received for services billed (19,937 ) — Services provided and billed in current period 112,845 — Payments received for services billed in current period (93,475 ) — Deferred commissioning period revenue — 2,110 Closing balance on June 30, 2019 23,809 (29,186 ) (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	Liquefaction services revenue recognized comprises the following amounts: Six months ended June 30, (in thousands of $) 2019 2018 Base tolling fee (1) 102,250 17,427 Amortization of deferred commissioning period billing (2) 2,110 357 Amortization of Day 1 gain (3) 4,975 841 Other (287 ) (48 ) Total 109,048 18,577 (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 asset 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.

(Loss)_Earnings Per Share (Tabl

(Loss)/Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
Schedule of (Losses) Earnings Per Share	The components of the numerator for the calculation of basic and diluted EPS are as follows: (in thousands of $) Six months ended June 30, 2019 2018 Net (loss)/income attributable to Golar LNG Limited stockholders - basic and diluted (154,423 ) 15,317 The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) Six months ended June 30, 2019 2018 Basic: Weighted average number of common shares outstanding 100,802 100,628 Dilutive: Dilutive impact of share options — 100 Weighted average number of common shares outstanding 100,802 100,728 (Loss)/earnings per share are as follows: Six months ended June 30, 2019 2018 Basic and diluted $ (1.53 ) $ 0.15

Other Financial Items, Net (Tab

Other Financial Items, Net (Tables)	6 Months Ended
	Jun. 30, 2019
Other Income and Expenses [Abstract]
Derivative Instruments, Gain (Loss)	(Losses)/gains on derivative instruments comprise of the following: (in thousands of $) Six months ended June 30, 2019 2018 Mark-to-market adjustment for interest rate swap derivatives (12,226 ) 7,713 Mark-to-market adjustment for equity derivatives (12,605 ) (4,374 ) Interest income on undesignated interest rate swaps 4,093 2,596 Mark-to-market adjustment for foreign exchange swap derivatives 320 (367 ) Unrealized mark-to-market losses on Earn-Out Units — (4,500 ) (20,418 ) 1,068
Schedule of Other Financial Items	Other financial items, net comprise of the following: (in thousands of $) Six months ended June 30, 2019 2018 Foreign exchange loss on operations (573 ) (618 ) Amortization of debt guarantee 633 361 Financing arrangement fees and other costs (3,480 ) (53 ) Others 81 (164 ) (3,339 ) (474 )

Operating Lease (Tables)

Operating Lease (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Lessor, Operating Lease, Payments to be Received, Maturity	The minimum contractual future revenues to be received on non-cancellable time charter leases in respect of our vessels as of June 30, 2019 , were as follows: Period ending December 31, (in thousands of $) 2019 20,079 2020 6,580 Total 26,659
Operating Lease, Lease Income	The components of operating lease income were as follows: Six months ended June 30, 2019 (in thousands of $) Operating lease income 22,001 Variable lease income (1) 2,698 Total operating lease income 24,699 (1) "Variable lease income" is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases.
Lease, Cost	The components of operating lease cost were as follows: (in thousands of $) Six months ended June 30, 2019 Operating lease cost (1) 3,430 Variable lease cost (2) 975 Total operating lease cost 4,405 (1) "Operating lease cost" includes short-term lease cost. (2) "Variable lease cost" is excluded from lease payments that comprise the operating lease liability.
Lessee, Operating Lease, Liability, Maturity	The maturity of our lease liabilities is as follows: (in thousands of $) Year ending December 31, Operating leases 2019 (1) 2,304 2020 3,452 2021 2,288 2022 1,223 2023 491 Thereafter 2,462 Total operating lease liabilities on June 30, 2019 12,220 (1) For the six months ending December 31, 2019 .

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Bareboat Charters	A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of June 30, 2019, are shown below: (in thousands of $) 2019 (1) 2020 2021 2022 2023 2024+ Golar Glacier 8,620 17,147 17,100 17,100 17,100 12,884 Golar Kelvin 8,620 17,147 17,100 17,100 17,100 15,695 Golar Snow 8,620 17,147 17,100 17,100 17,100 15,695 Golar Ice 8,620 17,147 17,100 17,100 17,100 18,599 Golar Tundra (2) 10,284 19,963 19,196 18,449 17,703 30,527 Golar Seal 6,840 13,717 13,717 13,717 13,754 27,433 Golar Crystal (2) 5,617 11,151 11,066 11,016 10,952 35,092 Hilli (2) 58,322 113,845 109,915 105,984 102,148 389,916 (1) For the six months ending December 31, 2019 . (2) The payment obligations relating to the Golar Tundra , Golar Crystal and Hilli above includes variable rental payments due under the lease based on an assumed LIBOR plus margin.
Schedule of Variable Interest Entities	The assets and liabilities of Gimi MS that most significantly impact our consolidated balance sheet are as follows: (in thousands of $) June 30, 2019 Balance sheet Current assets 48,328 Non-current assets 187,056 Current liabilities (40,837 ) The most significant impact of Gimi MS VIE's operations on our unaudited consolidated statements of cash flows, are as follows: (in thousands of $) Six months ended June 30, 2019 Statement of cash flows Additions to asset under development 105,339 The assets and liabilities of these lessor VIEs that most significantly impact our consolidated balance sheet as of June 30, 2019 and December 31, 2018, are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli June 30, 2019 December 31, 2018 Assets Total Total Restricted cash and short-term deposits 10,652 9 8,707 11,346 — 23,370 4,103 56,789 114,976 176,428 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 146,203 155,626 144,742 120,748 11,065 — 5,748 139,884 724,016 646,513 Long-term interest bearing debt - non-current portion (1) — — — — 102,256 123,105 88,036 718,800 1,032,197 1,200,774 146,203 155,626 144,742 120,748 113,321 123,105 93,784 858,684 1,756,213 1,847,287 (1) Where applicable, these balances are net of deferred finance charges. The assets and liabilities of Hilli LLC (1) that most significantly impact our consolidated balance sheet are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Balance sheet Current assets 112,646 172,554 Non-current assets 1,366,869 1,392,713 Current liabilities (200,633 ) (278,728 ) Non-current liabilities (805,686 ) (842,786 ) (1) 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 unaudited consolidated statements of income, and unaudited consolidated statements of cash flows, are as follows: (in thousands of $) Six months ended June 30, 2019 Six months ended June 30, 2018 Statement of operations Liquefaction services revenue 109,048 18,577 Realized and unrealized gains on the oil derivative instrument 8,145 111,348 Statement of cash flows Net debt repayments 39,297 — Net debt receipts — 928,280

Restricted Cash and Short Ter_2

Restricted Cash and Short Term Deposits (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Restrictions on Cash and Cash Equivalents	Our restricted cash and short-term deposits balances are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Restricted cash relating to the total return equity swap 96,763 82,863 Restricted cash in relation to the Hilli 151,957 174,597 Restricted cash and short-term deposits held by lessor VIEs 114,976 176,428 Collateral on the Margin Loan Facility 33,413 33,413 Restricted cash relating to the $1.125 billion debt facility 7,648 17,657 Restricted cash relating to office lease 786 777 Bank guarantee 43 691 Total restricted cash and short-term deposits 405,586 486,426 Less: Amounts included in current restricted cash and short-term deposits (252,843 ) (332,033 ) Long-term restricted cash 152,743 154,393

Asset Under Development (Tables

Asset Under Development (Tables)	6 Months Ended
	Jun. 30, 2019
Extractive Industries [Abstract]
Schedule for Assets Under Development	(in thousands of $) June 30, 2019 Opening asset under development balance 20,000 Transfer from other non-current assets (note 13) 31,048 Additions 127,444 Interest costs capitalized 1,888 Other costs capitalized 6,580 Closing asset under development balance 186,960
Contractual Obligation, Fiscal Year Maturity	As at June 30, 2019, the estimated timing of the outstanding payments in connection with the Gimi conversion are as follows: Period ending December 31, (in thousands of $) June 30, 2019 2019 (1) 235,923 2020 364,748 2021 213,203 2022 230,724 2023 134,231 1,178,829 (1) For the six months ending December 31, 2019

Investments in Affiliates and_2

Investments in Affiliates and Joint Ventures (Tables)	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Six months ended June 30, (in thousands of $) 2019 2018 Share of net (losses)/earnings in Golar Partners (27,659 ) 8,630 Share of net loss in Golar Power (10,923 ) (12,861 ) Share of net loss in OneLNG — (2,047 ) Share of net (losses)/earnings in others (858 ) 63 Share of net loss in Avenir (429 ) — (39,869 ) (6,215 ) The carrying amounts of our investments in our equity method investments as at June 30, 2019 and December 31, 2018 are as follows: (in thousands of $) June 30, 2019 December 31, 2018 Golar Partners 225,094 271,160 Golar Power 263,526 266,151 Avenir 28,927 28,710 Others 4,991 5,761 Equity in net assets of affiliates 522,538 571,782

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Components of Other Non-current Assets	Other non-current assets comprise of the following: (in thousands of $) June 30, 2019 December 31, 2018 Oil derivative instrument (1) 85,572 84,730 Operating lease right-of-use-assets (2) 12,093 — Investment in OLT-O (3) — 7,347 Other non-current assets (4) 18,780 40,729 Mark-to-market interest rate swaps valuation 218 6,298 116,663 139,104 (1) "Oil derivative instrument" refers to a derivative embedded in the Hilli LTA. See note 2 for further details. (2) Following the adoption of ASC 842, the balance sheet presents right-of-use-assets which mainly comprise of our office leases. This standard has been adopted under a modified retrospective transition approach as of January 1, 2019 . (3) Investment in 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, representing a 2.7% interest in OLT-O’s issued share capital. In May 2019 , a major shareholder sold its shareholding which triggered a re-assessment of the carrying value of our investment in OLT-O. This resulted in an impairment charge of $7.3 million for the write down of the carrying value in our investment in OLT-O. (4) "Other non-current assets" as of June 30, 2019 includes payments made for long lead items ordered in preparation for the conversion of the Viking into an FSRU. As of June 30, 2019 the aggregate carrying value of Viking long lead items was $9.1 million

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Components of Debt	As of June 30, 2019 , and December 31, 2018 , our debt was as follows: (in thousands of $) June 30, 2019 December 31, 2018 Golar Arctic facility 54,650 58,300 Golar Viking facility 44,271 46,875 2017 convertible bonds 360,665 353,661 Margin loan 100,000 100,000 $1.125 billion facility 162,873 173,732 Subtotal (excluding lessor VIE loans) 722,459 732,568 ICBCL VIE loans (1) 568,608 609,220 CCBFL VIE loan (1) 123,105 123,524 CMBL VIE loan (1) 113,321 121,741 COSCO Shipping VIE loan (1) 94,351 97,163 CSSC VIE loan (1) 858,684 897,980 Total debt 2,480,528 2,582,196 Less: Deferred finance charges, net (13,020 ) (16,837 ) Total debt, net of deferred financing costs 2,467,508 2,565,359 At June 30, 2019 , our debt, net of deferred financing costs, is broken down as follows: Golar debt VIE debt (1) Total debt (in thousands of $) Current portion of long-term debt and short-term debt 78,307 724,016 802,323 Long-term debt 632,988 1,032,197 1,665,185 Total 711,295 1,756,213 2,467,508 (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 9).

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive (Loss) Income (Tables)	6 Months Ended
	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Schedule of Accumulated Other Comprehensive (Loss) Income	The components of accumulated other comprehensive loss consisted of the following: (in thousands of $) Pension and post-retirement benefit plan adjustments Share of affiliates' comprehensive income Total accumulated comprehensive loss Balance at December 31, 2017 (12,799 ) 5,030 (7,769 ) Other comprehensive loss — (24,137 ) (24,137 ) Balance at June 30, 2018 (12,799 ) (19,107 ) (31,906 ) Balance at December 31, 2018 (9,218 ) (19,294 ) (28,512 ) Other comprehensive income — 651 651 Balance at June 30, 2019 (9,218 ) (18,643 ) (27,861 )

Financial Instruments (Tables)

Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Carrying Values and Estimated Values of Financial Instruments	The carrying values and estimated fair values of our financial instruments at June 30, 2019 and December 31, 2018 are as follows: June 30, 2019 December 31, 2018 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents Level 1 139,834 139,834 217,835 217,835 Restricted cash and short-term deposits Level 1 405,586 405,586 486,426 486,426 Current portion of long-term debt and short-term debt (1)(2) Level 2 (806,999 ) (906,999 ) (732,184 ) (732,184 ) Long-term debt - convertible bonds (2) Level 2 (360,665 ) (372,651 ) (353,661 ) (373,029 ) Long-term debt (2) Level 2 (1,312,864 ) (1,212,864 ) (1,496,351 ) (1,496,351 ) Derivatives: Oil derivative instrument (3)(6) Level 2 85,572 85,572 84,730 84,730 Interest rate swaps asset (3)(4) Level 2 1,928 1,928 10,770 10,770 Interest rate swaps liability (3)(4) Level 2 (3,384 ) (3,384 ) — — Foreign exchange swaps asset (3) Level 2 92 92 — — Foreign exchange swaps liability (3) Level 2 (1,094 ) (1,094 ) (1,322 ) (1,322 ) Total return equity swap liability (3)(4)(5) Level 2 (83,410 ) (83,410 ) (70,804 ) (70,804 ) (1) The carrying amounts of our short-term debt 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 above are gross of the deferred finance charges amounting to $ 13.0 million and $ 16.8 million at June 30, 2019 and December 31, 2018 , respectively. (3) Derivative liabilities are captured within other current liabilities and derivative assets are generally captured within other current assets and non-current assets on the balance sheet. (4) 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. (5) 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. (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 and short-term oil prices obtained from quoted prices in active markets.
Schedule of Designated Cash Flow Hedges	As of June 30, 2019 , 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 $) Notional value Maturity dates Fixed interest rates Interest rate swaps: Receiving floating, pay fixed 950,000 2019 to 2025 1.28% to 2.37%
Offsetting Assets	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 June 30, 2019 and December 31, 2018 would be adjusted as detailed in the following table: June 30, 2019 December 31, 2018 (in thousands of $) 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 Total asset derivatives 1,928 (917 ) 1,011 10,770 — 10,770 Total liability derivatives (3,384 ) 917 (2,467 ) — — —
Offsetting Liabilities	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 June 30, 2019 and December 31, 2018 would be adjusted as detailed in the following table: June 30, 2019 December 31, 2018 (in thousands of $) 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 Total asset derivatives 1,928 (917 ) 1,011 10,770 — 10,770 Total liability derivatives (3,384 ) 917 (2,467 ) — — —

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The table below summarizes our earnings generated from our participation in the Cool Pool: Six Months Ended (in thousands of $) 2019 2018 Time and voyage charter revenues 43,332 64,605 Time charter revenues - collaborative arrangement 23,359 19,353 Voyage, charterhire and commission expenses (8,092 ) (8,600 ) Voyage, charterhire and commission expenses - collaborative arrangement (18,933 ) (30,897 ) Net income from the Cool Pool 39,666 44,461 Receivables from other related parties: (in thousands of $) June 30, 2019 December 31, 2018 Cool Pool 11,205 43,985 11,205 43,985 Net revenues: The transactions with OneLNG and its subsidiaries for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue — 1,399 Total — 1,399 Receivables: The balances with OneLNG and its subsidiaries as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances due from OneLNG (a) 5,207 8,169 Total 5,207 8,169 Net revenues (expenses): The transactions with Golar Partners and its subsidiaries for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue (a) 4,747 3,877 Ship management fees revenue (b) 2,230 2,600 Interest expense on deposits payable (c) — (4,484 ) Total 6,977 1,993 Payables: The balances with Golar Partners and its subsidiaries as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances owing to Golar Partners and affiliates (d) 247 4,091 Methane Princess lease security deposit movement (e) (2,383 ) (2,835 ) Total (2,136 ) 1,256 a) Management and administrative services agreement - On March 30, 2011, Golar Partners entered into a management and administrative services agreement with Golar Management Limited ("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. b) 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. c) Interest expense on deposits payable 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 in return we were 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 was applied to the net sale price of the Hilli Disposal (defined below) on July 12, 2018 . Deposit received from Golar Partners - On August 15, 2017, we entered into the Hilli Sale Agreement with Golar Partners for the Hilli, or the Hilli Disposal, from the Sellers of the Hilli Common Units in Hilli LLC. On the Closing Date of the Hilli Disposal, Hilli LLC will 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 Perenco and SNH under an eight -year LTA. Concurrent 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 applied the deposit received and interest accrued to the purchase price on July 12, 2018, upon completion of the Hilli Disposal. We have accounted for $ nil and $2.7 million , and $ nil and $1.8 million from the above arrangements as interest expense on the Deferred Purchase Price and the $70 million deposit for the six months ended June 30, 2019 and 2018 , respectively. d) Trading balances - Receivables and payables with Golar Partners and its subsidiaries are comprised primarily of unpaid management fees, interest expense and expenses for management, advisory and administrative services and may include working capital adjustments with respect to 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. e) 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 the Methane Princess Lease. 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. The transactions with Golar Power and its affiliates for the six months ended June 30, 2019 and 2018 consisted of the following: Six months ended (in thousands of $) 2019 2018 Management and administrative services revenue 3,011 2,457 Ship management fees income 606 700 Debt guarantee compensation (a) 633 361 Other — (247 ) Total 4,250 3,271 Payables: The balances with Golar Power and its affiliates as of June 30, 2019 and December 31, 2018 consisted of the following: (in thousands of $) June 30, 2019 December 31, 2018 Trading balances due to Golar Power and affiliates (b) (2,583 ) (5,417 ) Total (2,583 ) (5,417 ) a) Debt guarantee compensation - In connection with the closing of the formation of the joint venture Golar Power with Stonepeak, Golar Power entered into agreements to compensate Golar in relation to certain debt guarantees relating to Golar Power and its subsidiaries. This compensation amounted to an aggregate of $0.6 million and $0.4 million income for the six months ended June 30, 2019 and 2018 , respectively. b) Trading balances - Receivables and payables with Golar Power and its subsidiaries are comprised primarily of unpaid management fees, charterhire expenses, advisory and administrative services and may include working capital adjustments in connection with the initial formation of the joint venture and transaction with Stonepeak. 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. They primarily relate to recharges for trading expenses paid on behalf of Golar Power, including ship management and administrative service fees due to us.

Other Commitments and Conting_2

Other Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Assets Pledged	(in thousands of $) June 30, 2019 December 31, 2018 Book value of vessels secured against long-term loans 3,165,857 3,244,291

General (Details)

General (Details) $ in Thousands	Apr. 16, 2019USD ($)	Feb. 28, 2019USD ($)	Jun. 30, 2019USD ($)carrier	Apr. 30, 2019USD ($)
Property, Plant and Equipment [Line Items]
Term of charter		20 years
Contractual obligation | $			$ 1,178,829	$ 1,300,000
Golar LNG Partners
Property, Plant and Equipment [Line Items]
Number of carriers operated by other			10
Golar Power
Property, Plant and Equipment [Line Items]
Number of carriers operated by other			3
LNG Carrier | LNG Carrier
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated			12
LNG Carrier | LNG Carrier | Golar LNG Limited, Golar LNG Partners, and Golar Power
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated			18
LNG Carrier | Floating Storage Regasification Unit
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated			1
LNG Carrier | Floating Storage Regasification Unit | Golar LNG Limited, Golar LNG Partners, and Golar Power
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated			8
LNG Carrier | FLNG
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated			1
$700 million facility
Property, Plant and Equipment [Line Items]
Long-term line of credit | $	$ 700,000
Long-term debt, term	7 years
Amortization term	12 years
Gimi MS | FLNG
Property, Plant and Equipment [Line Items]
Ownership percentage	30.00%
Long-term purchase commitment, percentage	30.00%
Gimi Conversion
Property, Plant and Equipment [Line Items]
Term of charter		20 years
Contractual obligation | $		$ 1,300,000
Expected future revenues, net of operating costs | $		215,000
Long-term line of credit | $		$ 700,000
Gimi Conversion | Keppel Capital
Property, Plant and Equipment [Line Items]
Long-term purchase commitment, percentage		30.00%
Gimi Conversion | $700 million facility
Property, Plant and Equipment [Line Items]
Long-term debt, term		7 years
Amortization term		12 years

Accounting Policies - Derivativ

Accounting Policies - Derivatives (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Derivative [Line Items]
Change in fair value of derivative instruments	$ 25,152	$ 1,528
Change in fair value of oil derivative instrument	(750)	(108,300)
Other current and non-current assets	(11,790)	6,443
Other current and non-current liabilities		39,037
Gains on derivative instruments	(20,418)	1,068
Other financial items, net	$ (3,339)	(474)
Previously Reported
Derivative [Line Items]
Change in fair value of derivative instruments		0
Change in fair value of oil derivative instrument		0
Other current and non-current assets		(105,056)
Other current and non-current liabilities		43,764
Gains on derivative instruments		0
Other financial items, net		594
Restatement Adjustment
Derivative [Line Items]
Change in fair value of derivative instruments		1,528
Change in fair value of oil derivative instrument		(108,300)
Other current and non-current assets		111,499
Other current and non-current liabilities		(4,727)
Gains on derivative instruments		1,068
Other financial items, net		$ (1,068)

Accounting Policies Accounting

Accounting Policies Accounting Policies - Price risk derivatives (Details) - FLNG derivative - FLNG - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Price Risk Derivatives [Line Items]
Realized gain on oil derivative instrument	$ 7,395
Realized gain on oil derivative instrument		$ 3,048
Unrealized gain on oil derivative instrument	750
Unrealized gain on oil derivative instrument		108,300
Gain on FLNG derivative instrument	$ 8,145	$ 111,348

Accounting Policies (Details)

Accounting Policies (Details) $ in Thousands	1 Months Ended		6 Months Ended		12 Months Ended
	May 31, 2019USD ($)	Mar. 31, 2019USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Dec. 31, 2018vessel
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Asset impairment charges			$ 7,347	$ 0
Golar Viking
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Asset impairment charges		$ 34,300
OLT Offshore LNG Toscana
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Impairment losses, investments	$ 7,300
Variable Interest Entity, Primary Beneficiary
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Number of vessels in sale and leaseback transaction | vessel					8

Recently Issued Accounting St_3

Recently Issued Accounting Standards Recently Issued Accounting Standards (Details) - Accounting Standards Update 2016-02 $ in Millions	Jan. 01, 2019USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease, liability	$ 15.8
Operating lease, liability, current	5.5
Operating lease, liability, noncurrent	$ 10.3

Segment Information - Narrative

Segment Information - Narrative (Details)	6 Months Ended
	Jun. 30, 2019segment
Segment Reporting [Abstract]
Number of Reportable Segments	3

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	May 31, 2019	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Total operating revenues		$ 211,032	$ 125,564
Depreciation and amortization		(56,284)	(36,866)
Other operating expenses		(122,165)	(115,230)
Impairment of long-term assets		(41,597)	0
Other operating gains (note 18)		14,443	111,366
Operating (loss)/income		5,429	84,834
Inter segment and segment operating income/(loss)		5,429	84,834
Equity in net losses of affiliates		(39,869)	(6,215)
Total assets		4,624,297		$ 4,806,595
Investments in affiliates		522,538		571,782
Operating Segments | Vessel Operations
Segment Reporting Information [Line Items]
Total operating revenues		101,984	106,987
Depreciation and amortization		(32,182)	(32,775)
Other operating expenses		(93,305)	(103,058)
Impairment of long-term assets		(41,597)	0
Other operating gains (note 18)		9,260	10,000
Operating (loss)/income		(55,840)	(18,846)
Inter segment and segment operating income/(loss)		(55,498)	(18,641)
Equity in net losses of affiliates		(28,946)	8,693
Total assets		2,683,867		2,990,506
Investments in affiliates		259,012		305,631
Operating Segments | FLNG
Segment Reporting Information [Line Items]
Total operating revenues		109,048	18,577
Depreciation and amortization		(24,102)	(4,091)
Other operating expenses		(28,860)	(12,172)
Impairment of long-term assets		0	0
Other operating gains (note 18)		5,183	101,366
Operating (loss)/income		61,269	103,680
Inter segment and segment operating income/(loss)		61,269	103,680
Equity in net losses of affiliates		0	(2,047)
Total assets		1,682,697		1,555,389
Investments in affiliates		0		0
Operating Segments | Power
Segment Reporting Information [Line Items]
Total operating revenues		0	0
Depreciation and amortization		0	0
Other operating expenses		0	0
Impairment of long-term assets		0	0
Other operating gains (note 18)		0	0
Operating (loss)/income		0	0
Inter segment and segment operating income/(loss)		0	0
Equity in net losses of affiliates		(10,923)	(12,861)
Total assets		263,526		266,151
Investments in affiliates		263,526		266,151
Intersegment Eliminations
Segment Reporting Information [Line Items]
Total operating revenues		0	0
Depreciation and amortization		0	0
Other operating expenses		0	0
Impairment of long-term assets		0	0
Other operating gains (note 18)		0	0
Operating (loss)/income		0	0
Inter segment and segment operating income/(loss)		(342)	(205)
Equity in net losses of affiliates		0	0
Total assets		(5,793)		(5,451)
Investments in affiliates		0		$ 0
Intersegment Eliminations | Vessel Operations
Segment Reporting Information [Line Items]
Inter segment and segment operating income/(loss)		342	205
Intersegment Eliminations | FLNG
Segment Reporting Information [Line Items]
Inter segment and segment operating income/(loss)		0	0
Intersegment Eliminations | Power
Segment Reporting Information [Line Items]
Inter segment and segment operating income/(loss)		$ 0	$ 0
OLT Offshore LNG Toscana
Segment Reporting Information [Line Items]
Impairment losses, investments	$ 7,300

Segment information - Revenue f

Segment information - Revenue from external customers (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 211,032	$ 125,564
Revenue from Contract with Customer Benchmark | Customer Concentration Risk | The Cool Pool
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 66,691	$ 83,959
Concentration risk, percentage	33.00%	74.00%
Revenue from Contract with Customer Benchmark | Customer Concentration Risk | Perenco and SNH
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 109,048	$ 18,577
Concentration risk, percentage	54.00%	16.00%

Revenue - Change in Contract Ba

Revenue - Change in Contract Balances (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)
Change in Contract with Customer, Asset [Abstract]
Contract with customer, asset, net, beginning balance	$ 24,376
Payments received for services billed	(19,937)
Services provided and billed in current period	112,845
Payments received for services billed in current period	(93,475)
Contract with customer, asset, net, ending balance	23,809
Change in Contract with Customer, Liability [Abstract]
Contract with customer, liability, beginning balance	(31,296)
Deferred commissioning period revenue	2,110
Contract with customer, liability, ending balance	$ (29,186)

Revenue - Management Fee Revenu

Revenue - Management Fee Revenue (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Amounts due from related parties	$ 5,207	$ 9,425
Amounts due to related parties	4,719	5,417
Golar LNG Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Amounts due from related parties	3,100	3,100
Amounts due to related parties	$ 3,700	$ 4,300

Revenue - Liquefaction Services

Revenue - Liquefaction Services Revenue (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)$ / barrel	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	$ 211,032	$ 125,564
Oil price per barrel (in usd per barrel) | $ / barrel		60
Contract with customer, liability, revenue recognized		$ 33,800
Derivative liability	3,384		$ 0
Liquefaction Services
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	109,048	18,577
Amortization of deferred commissioning period billing	2,110	357
Amortization of Day 1 gain	4,975	841
Other	(287)	(48)
Base tolling fee
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	$ 102,250	$ 17,427
FLNG
Disaggregation of Revenue [Line Items]
Derivative liability				$ 79,600

(Loss)_Earnings Per Share (Deta

(Loss)/Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Net (loss)/income attributable to Golar LNG Limited stockholders - basic and diluted	$ (154,423)	$ 15,317
Weighted average number of common shares outstanding, basic (in shares)	100,802	100,628
Dilutive impact of share options (in shares)	0	100
Weighted average number of common shares outstanding, basic and diluted (in shares)	100,802	100,728
Losses per share
Basic and diluted (in USD per share)	$ (1.53)	$ 0.15

- Schedule of Other Financial I

- Schedule of Other Financial Items (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
(Losses)/gains on derivative instruments	$ (20,418)	$ 1,068
Foreign exchange loss on operations	(573)	(618)
Amortization of debt guarantee	633	361
Financing arrangement fees and other costs	(3,480)	(53)
Others	81	(164)
Other Financial Items	(3,339)	(474)
Interest Rate Swaps
Derivative Instruments, Gain (Loss) [Line Items]
(Losses)/gains on derivative instruments	(12,226)	7,713
Interest income on undesignated interest rate swaps	4,093	2,596
Equity Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
(Losses)/gains on derivative instruments	(12,605)	(4,374)
Foreign Exchange Swaps
Derivative Instruments, Gain (Loss) [Line Items]
(Losses)/gains on derivative instruments	320	(367)
Earn-out Units
Derivative Instruments, Gain (Loss) [Line Items]
(Losses)/gains on derivative instruments	$ 0	$ (4,500)

Operating Lease - Narrative (De

Operating Lease - Narrative (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Lessor, Lease, Description [Line Items]
Carrying value of vessel	$ 3,190,969	$ 3,271,379
Right-of-use asset obtained in exchange for operating lease liability	$ 12,100
Weighted average lease term	5 years 7 months 6 days
Weighted average discount rate, percent	5.50%
Minimum
Lessor, Lease, Description [Line Items]
Lessor, operating lease, term of contract	8 months
Maximum
Lessor, Lease, Description [Line Items]
Lessor, operating lease, term of contract	60 months
Hilli
Lessor, Lease, Description [Line Items]
Carrying value of vessel	$ 1,239,500

Operating Lease - Minimum Contr

Operating Lease - Minimum Contractual Future Revenues to be Received (Details) $ in Thousands	Jun. 30, 2019USD ($)
Leases [Abstract]
2019	$ 20,079
2020	6,580
Total	$ 26,659

Operating Lease - Operating Lea

Operating Lease - Operating Lease Income (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)
Leases [Abstract]
Operating lease income	$ 22,001
Variable lease income	2,698
Total operating lease income	$ 24,699

Operating Lease - Operating L_2

Operating Lease - Operating Lease Cost (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)
Leases [Abstract]
Operating lease cost	$ 3,430
Variable lease cost	975
Total operating lease cost	$ 4,405

Operating Lease - Maturity of L

Operating Lease - Maturity of Lease Liability (Details) $ in Thousands	Jun. 30, 2019USD ($)
Leases [Abstract]
2019	$ 2,304
2020	3,452
2021	2,288
2022	1,223
2023	491
Thereafter	2,462
Total operating lease liabilities on June 30, 2019	$ 12,220

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) $ in Thousands	6 Months Ended		12 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)vessel	Dec. 31, 2018vessel	Apr. 16, 2019
Variable Interest Entity [Line Items]
Interest expense | $	$ 53,728	$ 38,012
Net cash received in financing activities | $	146,760	$ (328,799)
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction			8
Sale and leaseback term		10 years
Interest expense | $	35,900	$ 19,100
Net cash received in financing activities | $	$ (91,600)	$ (864,700)
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction		4
Variable Interest Entity, Primary Beneficiary | CMBL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction		1
Variable Interest Entity, Primary Beneficiary | CCBFL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction		1
Variable Interest Entity, Primary Beneficiary | COSCO Shipping Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction		1
Variable Interest Entity, Primary Beneficiary | CSSC
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction		1
FLNG | Gimi MS
Variable Interest Entity [Line Items]
Ownership percentage				30.00%

Variable Interest Entities - Su

Variable Interest Entities - Summary of Bareboat Charters (Details) $ in Thousands	Jun. 30, 2019USD ($)
Variable Interest Entity [Line Items]
2019	$ 2,304
2020	3,452
2021	2,288
2022	1,223
2023	491
2024	2,462
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement | Golar Glacier
Variable Interest Entity [Line Items]
2019	8,620
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024	12,884
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement | Golar Kelvin
Variable Interest Entity [Line Items]
2019	8,620
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024	15,695
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement | Golar Snow
Variable Interest Entity [Line Items]
2019	8,620
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024	15,695
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement | Golar Ice
Variable Interest Entity [Line Items]
2019	8,620
2020	17,147
2021	17,100
2022	17,100
2023	17,100
2024	18,599
Variable Interest Entity, Primary Beneficiary | CMBL Agreement | Golar Tundra
Variable Interest Entity [Line Items]
2019	10,284
2020	19,963
2021	19,196
2022	18,449
2023	17,703
2024	30,527
Variable Interest Entity, Primary Beneficiary | CCBFL Agreement | Golar Seal
Variable Interest Entity [Line Items]
2019	6,840
2020	13,717
2021	13,717
2022	13,717
2023	13,754
2024	27,433
Variable Interest Entity, Primary Beneficiary | COSCO Shipping Agreement | Golar Crystal
Variable Interest Entity [Line Items]
2019	5,617
2020	11,151
2021	11,066
2022	11,016
2023	10,952
2024	35,092
Variable Interest Entity, Primary Beneficiary | CSSC | Hilli
Variable Interest Entity [Line Items]
2019	58,322
2020	113,845
2021	109,915
2022	105,984
2023	102,148
2024	$ 389,916

Variable Interest Entities - Sc

Variable Interest Entities - Schedule of Assets and Liabilities of Lessor VIEs (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Debt:
Current portion of long-term debt and short-term debt	$ 802,323	$ 730,257
Long-term interest bearing debt - non-current portion	1,665,185	1,835,102
Total liabilities	2,863,783	2,980,804
Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	114,976	176,428
Debt:
Current portion of long-term debt and short-term debt	724,016	646,513
Long-term interest bearing debt - non-current portion	1,032,197	1,200,774
Total liabilities	1,756,213	$ 1,847,287
ICBCL Agreement | Golar Glacier | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	10,652
Debt:
Current portion of long-term debt and short-term debt	146,203
Long-term interest bearing debt - non-current portion	0
Total liabilities	146,203
ICBCL Agreement | Golar Kelvin | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	9
Debt:
Current portion of long-term debt and short-term debt	155,626
Long-term interest bearing debt - non-current portion	0
Total liabilities	155,626
ICBCL Agreement | Golar Snow | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	8,707
Debt:
Current portion of long-term debt and short-term debt	144,742
Long-term interest bearing debt - non-current portion	0
Total liabilities	144,742
ICBCL Agreement | Golar Ice | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	11,346
Debt:
Current portion of long-term debt and short-term debt	120,748
Long-term interest bearing debt - non-current portion	0
Total liabilities	120,748
CMBL Agreement | Golar Tundra | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	0
Debt:
Current portion of long-term debt and short-term debt	11,065
Long-term interest bearing debt - non-current portion	102,256
Total liabilities	113,321
CCBFL Agreement | Golar Seal | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	23,370
Debt:
Current portion of long-term debt and short-term debt	0
Long-term interest bearing debt - non-current portion	123,105
Total liabilities	123,105
COSCO Shipping Agreement | Golar Crystal | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	4,103
Debt:
Current portion of long-term debt and short-term debt	5,748
Long-term interest bearing debt - non-current portion	88,036
Total liabilities	93,784
CSSC | Hilli | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	56,789
Debt:
Current portion of long-term debt and short-term debt	139,884
Long-term interest bearing debt - non-current portion	718,800
Total liabilities	$ 858,684

Variable Interest Entities - Fi

Variable Interest Entities - Financial Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Variable Interest Entity [Line Items]
Liquefaction services revenue	$ 211,032	$ 125,564
Realized and unrealized gain on oil derivative instrument	8,145	111,348
Net debt repayments	123,495	874,256
Net debt receipts	14,824	1,176,000
Additions to asset under development	105,339	116,715
Hilli | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Current assets	112,646		$ 172,554
Non-current assets	1,366,869		1,392,713
Current liabilities	(200,633)		(278,728)
Non-current liabilities	(805,686)		$ (842,786)
Realized and unrealized gain on oil derivative instrument	8,145	111,348
Net debt repayments	39,297	0
Net debt receipts	0	928,280
Golar Gimi | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Current assets	48,328
Non-current assets	187,056
Current liabilities	(40,837)
Additions to asset under development	105,339
Liquefaction Services
Variable Interest Entity [Line Items]
Liquefaction services revenue	109,048	18,577
Liquefaction Services | Hilli | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Liquefaction services revenue	$ 109,048	$ 18,577

Restricted Cash and Short Ter_3

Restricted Cash and Short Term Deposits (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 405,586,000	$ 486,426,000
Less: Amounts included in current restricted cash and short-term deposits	(252,843,000)	(332,033,000)	$ (276,289,000)	$ (222,265,000)
Long-term restricted cash	152,743,000	154,393,000	$ 176,029,000	$ 175,550,000
Return Equity Swap
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	96,763,000	82,863,000
Letter of Credit
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	151,957,000	174,597,000
Lessor VIEs
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	114,976,000	176,428,000
Office lease
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	786,000	777,000
Bank guarantee
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	43,000	691,000
Margin loan | Line of Credit
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	33,413,000	33,413,000
$1.125 billion facility | Interest-bearing Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	7,648,000	17,657,000
Secured Debt | Line of Credit | $1.125 billion facility
Restricted Cash and Cash Equivalents Items [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,125,000,000	$ 1,125,000,000

Asset Under Development (Detail

Asset Under Development (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Opening asset under development balance	$ 20,000
Closing asset under development balance	186,960
Gimi Conversion
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Opening asset under development balance	20,000
Transfer from other non-current assets (note 13)	31,048
Additions	127,444
Interest costs capitalized	1,888
Other costs capitalized	6,580
Closing asset under development balance	$ 186,960

Asset Under Development (Narrat

Asset Under Development (Narrative) (Details) - USD ($) $ in Thousands	Apr. 16, 2019	Feb. 28, 2019	Jun. 30, 2019	Apr. 30, 2019
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Term of charter		20 years
Contractual obligation			$ 1,178,829	$ 1,300,000
$700 million facility
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Long-term line of credit	$ 700,000
Long-term debt, term	7 years
Amortization term	12 years
Drawdown dependent on project spend	$ 300,000
FLNG | Gimi MS
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Ownership percentage	30.00%

Asset Under Development (Commit

Asset Under Development (Commitments) (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Apr. 30, 2019
Extractive Industries [Abstract]
2019	$ 235,923
2020	364,748
2021	213,203
2022	230,724
2023	134,231
Total	$ 1,178,829	$ 1,300,000

Investments in Affiliates and_3

Investments in Affiliates and Joint Ventures (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	$ (39,869)	$ (6,215)
Golar Partners
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	(27,659)	8,630
Golar Power
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	(10,923)	(12,861)
OneLNG
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	0	(2,047)
Avenir
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	(429)	0
Others
Schedule of Equity Method Investments [Line Items]
Equity in net losses of affiliates	$ (858)	$ 63

Investments in Affiliates and_4

Investments in Affiliates and Joint Ventures - Schedule of Carrying Amount of Equity Method Investments (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	$ 522,538	$ 571,782
Golar Partners
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	225,094	271,160
Golar Power
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	263,526	266,151
Avenir
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	28,927	28,710
Others
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	$ 4,991	$ 5,761

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	May 31, 2019	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018
Components of Other Non-Current Assets:
Operating lease right-of-use asset		$ 12,093	$ 0
Other non-current assets		18,780	40,729
Total other non-current assets		116,663	139,104
OLT Offshore LNG Toscana
Components of Other Non-Current Assets:
Investment in OLT Offshore LNG Toscana		0	7,347
Impairment losses, investments	$ 7,300
Interest Rate Swaps
Components of Other Non-Current Assets:
Derivatives		218	6,298
FLNG | FLNG derivative
Components of Other Non-Current Assets:
Derivatives		85,572	$ 84,730
Golar Viking
Components of Other Non-Current Assets:
Other non-current assets		9,100
Hilli Conversion to FLNG
Components of Other Non-Current Assets:
Transfer from other non-current assets		$ 31,000
OLT Offshore LNG Toscana
Components of Other Non-Current Assets:
Ownership percentage				2.70%

Debt - Components of Debt (Deta

Debt - Components of Debt (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Total debt	$ 2,480,528,000	$ 2,582,196,000
Subtotal (excluding lessor VIE loans)	722,459,000	732,568,000
Less: Deferred finance charges, net	(13,020,000)	(16,837,000)
Total debt, net of deferred financing costs	2,467,508,000	2,565,359,000
Secured Debt | Golar Arctic facility
Debt Instrument [Line Items]
Total debt	54,650,000	58,300,000
Secured Debt | Golar Viking facility
Debt Instrument [Line Items]
Total debt	44,271,000	46,875,000
Secured Debt | Margin loan
Debt Instrument [Line Items]
Total debt	100,000,000	100,000,000
Secured Debt | $1.125 billion facility
Debt Instrument [Line Items]
Total debt	162,873,000	173,732,000
Secured Debt | ICBC VIE loans
Debt Instrument [Line Items]
Total debt	568,608,000	609,220,000
Secured Debt | CCBFL VIE loan
Debt Instrument [Line Items]
Total debt	123,105,000	123,524,000
Secured Debt | CMBL VIE loan
Debt Instrument [Line Items]
Total debt	113,321,000	121,741,000
Secured Debt | COSCO Shipping VIE loan
Debt Instrument [Line Items]
Total debt	94,351,000	97,163,000
Secured Debt | CSSC VIE loan
Debt Instrument [Line Items]
Total debt	858,684,000	897,980,000
Convertible Debt | 2017 convertible bonds
Debt Instrument [Line Items]
Total debt	360,665,000	353,661,000
Line of Credit | Secured Debt | $1.125 billion facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,125,000,000	$ 1,125,000,000

Debt Debt - Summary (Details)

Debt Debt - Summary (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	$ 802,323
Long-term debt	1,665,185	$ 1,835,102
Total	2,467,508
VIE debt
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	724,016
Long-term debt	1,032,197	$ 1,200,774
Total	1,756,213
Golar
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	78,307
Long-term debt	632,988
Total	$ 711,295

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive (Loss) Income (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 1,825,791	$ 1,796,304
Other comprehensive income (loss)	651	(24,137)
Ending balance	1,760,514	1,842,695
Total accumulated comprehensive loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(28,512)	(7,769)
Ending balance	(27,861)	(31,906)
Pension and post-retirement benefit plan adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(9,218)	(12,799)
Other comprehensive income (loss)	0	0
Ending balance	(9,218)	(12,799)
Share of affiliates' comprehensive income
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(19,294)	5,030
Other comprehensive income (loss)	651	(24,137)
Ending balance	$ (18,643)	$ (19,107)

Financial Instruments (Details)

Financial Instruments (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Non-Derivatives:
Cash and cash equivalents	$ 139,834,000	$ 217,835,000	$ 375,067,000	$ 214,862,000
Restricted cash and short-term deposits, carrying value	405,586,000	486,426,000
Current portion of long-term debt and short-term debt, carrying value	(802,323,000)	(730,257,000)
Long-term debt	(1,665,185,000)	(1,835,102,000)
Derivatives:
Derivative asset	1,928,000	10,770,000
Derivative liability	(3,384,000)	0
Deferred finance charges	13,020,000	16,837,000
Interest Rate Swaps
Derivatives:
Notional value	250,000,000
Interest Rate Swaps | Cash Flow Hedging
Derivatives:
Notional value	$ 950,000,000
Interest Rate Swaps | Minimum | Cash Flow Hedging
Derivatives:
Fixed interest rates	1.28%
Interest Rate Swaps | Maximum | Cash Flow Hedging
Derivatives:
Fixed interest rates	2.37%
Carrying value | Level 1
Non-Derivatives:
Cash and cash equivalents	$ 139,834,000	217,835,000
Restricted cash and short-term deposits, carrying value	405,586,000	486,426,000
Carrying value | Level 2
Non-Derivatives:
Current portion of long-term debt and short-term debt, carrying value	(806,999,000)	(732,184,000)
Long-term debt - convertible bonds, carrying value	(360,665,000)	(353,661,000)
Long-term debt	(1,312,864,000)	(1,496,351,000)
Carrying value | Level 2 | Oil Derivative
Derivatives:
Derivative asset	85,572,000	84,730,000
Carrying value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	1,928,000	10,770,000
Derivative liability	(3,384,000)	0
Carrying value | Level 2 | Foreign Exchange Swaps
Derivatives:
Foreign exchange swaps asset	92,000	0
Foreign exchange swaps liability	(1,094,000)	(1,322,000)
Carrying value | Level 2 | Return Equity Swap
Derivatives:
Derivative liability	(83,410,000)	(70,804,000)
Fair value | Level 1
Non-Derivatives:
Cash and cash equivalents, fair value	139,834,000	217,835,000
Restricted cash and short-term deposits, fair value	405,586,000	486,426,000
Fair value | Level 2
Non-Derivatives:
Current portion of long-term debt and short-term debt, fair value	(906,999,000)	(732,184,000)
Long-term debt - convertible bonds, fair value	(372,651,000)	(373,029,000)
Long-term debt, fair value	(1,212,864,000)	(1,496,351,000)
Fair value | Level 2 | Oil Derivative
Derivatives:
Derivative asset	85,572,000	84,730,000
Fair value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	1,928,000	10,770,000
Derivative liability	(3,384,000)	0
Fair value | Level 2 | Foreign Exchange Swaps
Derivatives:
Foreign exchange swaps asset	92,000	0
Foreign exchange swaps liability	(1,094,000)	(1,322,000)
Fair value | Level 2 | Return Equity Swap
Derivatives:
Derivative liability	$ (83,410,000)	$ (70,804,000)

Financial Instruments - Offsett

Financial Instruments - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	$ 1,928	$ 10,770
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	(917)	0
Net amount	1,011	10,770
Total liability derivatives
Gross amounts presented in the consolidated balance sheet	(3,384)	0
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	917	0
Net amount	(2,467)	$ 0
Cash Collateral for Borrowed Securities	$ 96,800
Share Repurchase Forward Swap
Total liability derivatives
Percentage of total purchase price	20.00%

Related Party Transactions - Tr

Related Party Transactions - Transactions and balances with Golar Partners and Subsidiaries (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Total operating revenues	$ 211,032	$ 125,564
Due from (to) related party	11,205		$ 43,985
Golar LNG Partners
Related Party Transaction [Line Items]
Total	6,977	1,993
Due from (to) related party	(2,136)		1,256
Golar LNG Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Total operating revenues	4,747	3,877
Golar LNG Partners | Ship management fees income
Related Party Transaction [Line Items]
Total operating revenues	2,230	2,600
Golar LNG Partners | Interest expense on deposits payable
Related Party Transaction [Line Items]
Interest expense on deposits payable	0	$ (4,484)
Golar LNG Partners | Trading balances due to Golar Power and affiliates
Related Party Transaction [Line Items]
Due from (to) related party	247		4,091
Golar LNG Partners | Methane Princess security lease deposit movement
Related Party Transaction [Line Items]
Due from (to) related party	$ (2,383)		$ (2,835)

Related Party Transactions - Go

Related Party Transactions - Golar Partners and Subsidiaries Footnotes (Details)	Aug. 15, 2017USD ($)train	May 31, 2017USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Related Party Transaction [Line Items]
Due from (to) related party			$ 11,205,000		$ 43,985,000
Payments of dividends			0	$ 754,000
Deferred Purchase Price
Related Party Transaction [Line Items]
Interest expense, related party			$ 0	2,700,000
Golar LNG Partners
Related Party Transaction [Line Items]
Related party transaction rate			5.00%
Termination of related party agreement, period of written notice			120 days
Due from (to) related party			$ (2,136,000)		$ 1,256,000
Additional amount, percent per annum of Deferred Purchase Price		5.00%
Distributions from related party			18,300,000	26,200,000
Golar LNG Partners | Deposits Due to Affiliates
Related Party Transaction [Line Items]
Due from (to) related party		$ (107,200,000)
Golar LNG Partners | Hilli Disposal Interests | Purchase and Sale Agreement
Related Party Transaction [Line Items]
Disposal interest, equivalent percentage	50.00%
Number of liquefaction trains contracted | train	2
Total number of liquefaction trains | train	4
Liquefaction trains, contractual term	8 years
Golar LNG Partners | Deposit Received
Related Party Transaction [Line Items]
Related party transaction rate	5.00%
Related party transaction amount	$ 70,000,000		70,000,000	70,000,000
Golar LNG Partners | Deposits Due From Affiliates
Related Party Transaction [Line Items]
Interest expense, related party			0	$ 1,800,000
Golar LNG Partners | Disposal Costs Indemnification
Related Party Transaction [Line Items]
Related party costs			800,000
Dividends payable			$ 6,800,000
Golar LNG Partners | Golar Management
Related Party Transaction [Line Items]
Termination of related party agreement, period of written notice			30 days
Hilli | Golar LNG Partners
Related Party Transaction [Line Items]
Payments of dividends			$ 9,000,000

Related Party Transactions - _2

Related Party Transactions - Transactions and balances with Golar Power and Affiliates (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Total operating revenues	$ 211,032	$ 125,564
Due from (to) related party	11,205		$ 43,985
Golar LNG Partners
Related Party Transaction [Line Items]
Total	6,977	1,993
Due from (to) related party	(2,136)		1,256
Golar LNG Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Total operating revenues	4,747	3,877
Golar LNG Partners | Ship management fees income
Related Party Transaction [Line Items]
Total operating revenues	2,230	2,600
Golar LNG Partners | Trading balances due to Golar Power and affiliates
Related Party Transaction [Line Items]
Due from (to) related party	247		4,091
Golar Power
Related Party Transaction [Line Items]
Total	4,250	3,271
Due from (to) related party	(2,583)		(5,417)
Golar Power | Management and administrative services revenue
Related Party Transaction [Line Items]
Total operating revenues	3,011	2,457
Golar Power | Ship management fees income
Related Party Transaction [Line Items]
Total operating revenues	606	700
Golar Power | Debt guarantee compensation
Related Party Transaction [Line Items]
Ship management fees income	633	361
Golar Power | Other
Related Party Transaction [Line Items]
Other	0	$ (247)
Golar Power | Trading balances due to Golar Power and affiliates
Related Party Transaction [Line Items]
Due from (to) related party	(2,583)		(5,417)
Debt Guarantee | Golar Power
Related Party Transaction [Line Items]
Guarantor obligations, current carrying value	$ 376,800		$ 393,500

Related Party Transactions - _3

Related Party Transactions - Transactions and balances with OneLNG and Subsidiaries (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Due from (to) related party	$ 11,205		$ 43,985
OneLNG | Management and administrative services revenue
Related Party Transaction [Line Items]
Related party revenues	0	$ 1,399
OneLNG | Trading Balances Due from OneLNG
Related Party Transaction [Line Items]
Due from (to) related party	5,207		$ 8,169
Impairment of related party transaction	$ 3,000

Related Party Transactions - Ea

Related Party Transactions - Earnings Generated from Participation in The Cool Pool (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Related Party Transaction [Line Items]
Total operating revenues	$ 211,032	$ 125,564
Due from (to) related party	11,205		$ 43,985
The Cool Pool
Related Party Transaction [Line Items]
Net income (expenses) from related party transactions	39,666	44,461
Due from (to) related party	11,205		$ 43,985
Non-collaborative Arrangement
Related Party Transaction [Line Items]
Voyage and charterhire expenses	(11,994)	(10,107)
Non-collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Voyage and charterhire expenses	(8,092)	(8,600)
Collaborative Arrangement
Related Party Transaction [Line Items]
Voyage and charterhire expenses	(18,933)	(30,897)
Collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Voyage and charterhire expenses	(18,933)	(30,897)
Time and Voyage Charter
Related Party Transaction [Line Items]
Total operating revenues	68,031	76,433
Time and Voyage Charter | Non-collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Total operating revenues	43,332	64,605
Time Charter
Related Party Transaction [Line Items]
Total operating revenues	23,359	19,353
Time Charter | Collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Total operating revenues	$ 23,359	$ 19,353

Other Commitments and Conting_3

Other Commitments and Contingencies Other Commitments and Contingencies - Pledged Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Book value of vessels secured against long-term loans	$ 3,165,857	$ 3,244,291

Other Commitments and Conting_4

Other Commitments and Contingencies - Narrative (Details) $ / shares in Units, $ in Thousands, € in Millions	1 Months Ended	6 Months Ended		12 Months Ended
	Nov. 30, 2018$ / sharesshares	Jun. 30, 2019USD ($)tax_leaseshares	Jun. 30, 2019GBP (£)tax_lease	Dec. 31, 2003GBP (£)tax_lease	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jun. 30, 2019EUR (€)shares	Apr. 30, 2019USD ($)	Dec. 31, 2018USD ($)shares
Loss Contingencies [Line Items]
Number of tax leases | tax_lease				6
Gross cash benefit received from tax leases | £				£ 41,000,000
Number of tax leases terminated | tax_lease		5	5
Number of tax leases remaining | tax_lease		1	1
Contractual obligation		$ 1,178,829						$ 1,300,000
Minimum
Loss Contingencies [Line Items]
Estimate of possible exposure | £			£ 0
Maximum
Loss Contingencies [Line Items]
Estimate of possible exposure | £			£ 115,000,000
Shareholders' Agreement, Project to Fund Development of Pipeline Infrastructure and FSRU
Loss Contingencies [Line Items]
Contractual obligation | €							€ 1
Shareholders' Agreement, Project to Fund Development of Pipeline Infrastructure and FSRU | Maximum
Loss Contingencies [Line Items]
Contractual obligation | €							€ 15
ECGS
Loss Contingencies [Line Items]
Commitments and contingencies		$ 1,000
Avenir
Loss Contingencies [Line Items]
Shares issued (in shares) | shares	110,000,000
Common stock, par value per share (in dollars per share) | $ / shares	$ 1
Margin loan | Golar Partners, Common Units
Loss Contingencies [Line Items]
Number of common units pledged as security (in shares) | shares		21,226,586					21,226,586		21,226,586
Avenir
Loss Contingencies [Line Items]
Investment company, future amount									$ 18,000
Avenir | Founding Partners
Loss Contingencies [Line Items]
Investment company, future amount									$ 72,000
Stolt-Nielsen Ltd and Höegh LNG Holdings Ltd | Avenir
Loss Contingencies [Line Items]
Committed capital		$ 182,000
Other Operating Income (Expense)
Loss Contingencies [Line Items]
Loss contingency, receivable, proceeds		$ 9,300
Golar Viking Conversion | Scenario, Forecast
Loss Contingencies [Line Items]
Long term purchase commitments					$ 86,700	$ 8,700

Subsequent Events (Details)

Subsequent Events (Details) - Subsequent Event	1 Months Ended
	Aug. 31, 2019USD ($)
Margin loan | Revolving Credit Facility
Subsequent Event [Line Items]
Line of credit facility, maximum borrowing capacity	$ 110,000,000
Debt instrument, term	1 year
$150 Million Term Loan Facility | Term Loan Facility
Subsequent Event [Line Items]
Line of credit facility, maximum borrowing capacity	$ 150,000,000
Debt instrument, term	15 months
Debt instrument, extension period	9 months