Golar LNG Limited (GLNG) 6-K 31 Aug 18 2018 Q2 Current report (foreign) Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	GOLAR LNG LTD
Entity Central Index Key	1,207,179
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Document Type	6-K
Amendment Flag	false
Document Period End Date	Jun. 30, 2018

UNAUDITED CONSOLIDATED STATEMEN

UNAUDITED CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
Total operating revenues		$ 125,564	$ 53,518
Vessel operating expenses		38,911	25,043
Voyage and charterhire expenses		10,107	15,965
Administrative expenses		24,092	18,269
Project development expenses		11,223	4,277
Depreciation and amortization		36,866	42,552
Total operating expenses		152,096	118,878
Realized and unrealized gain on FLNG derivative instrument		111,348	0
Other operating gains and losses	[1]	18	0
Total other operating income		111,366	0
Operating gain (loss)		84,834	(65,360)
Other non-operating income
Other		0	206
Total other non-operating income		0	206
Financial income (expenses)
Interest income		4,044	2,912
Interest expense		(38,012)	(39,710)
Other financial items, net		594	(7,928)
Net financial expenses		(33,374)	(44,726)
Income (loss) before taxes and equity in net losses of affiliates		51,460	(109,880)
Income taxes		(484)	(647)
Equity in net earnings (losses) of affiliates		(6,215)	(13,193)
Net income (loss)		44,761	(123,720)
Net income attributable to non-controlling interests		(29,444)	(15,931)
Net income (loss) attributable to stockholders of Golar LNG Ltd		$ 15,317	$ (139,651)
Basic and diluted loss per share (in USD per share)		$ 0.15	$ (1.39)
Cash dividends declared and paid per share (in USD per share)		$ 0.10	$ 0.10
Other Operating Gain		$ 10,000
Other Operating Loss		10,000
Time and Voyage Charter
Total operating revenues		76,433	$ 32,284
Time Charter
Total operating revenues		19,353	11,739
Liquefaction Services
Total operating revenues		18,577	0
Vessel and Other Management Fees
Total operating revenues		11,201	9,495
Collaborative Arrangement
Voyage and charterhire expenses		$ 30,897	$ 12,772
[1]	This represents initial amounts of $10.0 million recovered in connection with the ongoing arbitration proceedings arising from the delays and the termination of the Golar Tundra time charter with a former charterer, partially offset by a write off of $10.0 million of the trading balance with OneLNG, subsequent to the decision to dissolve OneLNG, as we deem it to be no longer recoverable (see note 16).

UNAUDITED CONSOLIDATED STATEME3

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 44,761	$ (123,720)
Other comprehensive (loss) income:
Net (loss) gain on qualifying cash flow hedging instruments	(5,038)	1,632
Net loss on foreign currency translation	(19,099)	0
Other comprehensive (loss) income	(24,137)	1,632
Comprehensive income (loss)	20,624	(122,088)
Comprehensive income (loss) attributable to:
Stockholders of Golar LNG Limited	(8,820)	(138,019)
Non-controlling interests	$ 29,444	$ 15,931

UNAUDITED CONSOLIDATED BALANCE

UNAUDITED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands		Jun. 30, 2018	Dec. 31, 2017
Current
Cash and cash equivalents		$ 375,067	$ 214,862
Restricted cash and short-term deposits		276,289	222,265
Trade accounts receivable	[1]	27,860	14,980
Inventories		7,443	7,408
Other current assets		16,557	6,047
Amounts due from related parties		10,912	7,898
Total current assets		714,128	473,460
Non-current
Restricted cash		176,029	175,550
Investments in affiliates		708,664	703,225
Asset under development		0	1,177,489
Vessels and equipment, net		3,342,677	2,077,059
Other non-current assets		251,476	157,504
Total assets		5,192,974	4,764,287
Current portion of long-term debt and short-term debt		868,725
Current
Current portion of long-term debt and short-term debt			1,384,933
Trade accounts payable		28,530	70,430
Accrued expenses		168,751	105,895
Other current liabilities		76,072	62,282
Amounts due to related parties		17,074	8,734
Total current liabilities		1,159,152	1,632,274
Non-current
Long-term debt		1,855,960	1,025,914
Amounts due to related parties		177,247	177,247
Other non-current liabilities		157,920	132,548
Total liabilities		3,350,279	2,967,983
Equity
Stockholders' equity		1,703,561	1,715,316
Non-controlling interests		139,134	80,988
Total liabilities and stockholders' equity		$ 5,192,974	$ 4,764,287
[1]	This includes amounts arising from transactions with related parties (see note 16).

UNAUDITED CONSOLIDATED STATEME5

UNAUDITED CONSOLIDATED STATEMENTS OF CASHFLOWS - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
OPERATING ACTIVITIES
Net income (loss)		$ 44,761	$ (123,720)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization		36,866	42,552
Amortization of deferred charges and debt guarantees		5,035	(667)
Equity in net earnings (losses) of affiliates		6,215	13,194
Dividends received	[1]	8,119	22,281
Compensation cost related to share options		5,367	3,875
Net foreign exchange loss		618	1,121
Change in assets and liabilities:
Trade accounts receivable		(12,880)	(1,989)
Inventories		(35)	447
Other current and non-current assets		(105,056)	714
Amounts due to related companies		5,687	(23,992)
Trade accounts payable		(5,135)	(2,319)
Accrued expenses		15,008	15,934
Other current and non-current liabilities		43,764	18,438
Net cash provided by (used in) operating activities		48,334	(34,131)
INVESTING ACTIVITIES
Additions to vessels and equipment		(1,801)	(1,093)
Additions to asset under development		(116,715)	(133,696)
Additions to investments in affiliates		(62,244)	(57,147)
Proceeds from dividends received, investing activities	[1]	18,335	3,374
Net cash used in investing activities		(162,425)	(188,562)
FINANCING ACTIVITIES
Proceeds from short-term and long-term debt		1,176,000	778,432
Repayments of short-term and long-term debt		(874,256)	(371,268)
Payment for capped call in connection with bond issuance		0	(31,194)
Cash effect of consolidating Hilli Lessor VIE	[2]	36,532	0
Cash dividends paid		(9,906)	(10,334)
Financing costs paid		1,183	0
Proceeds from exercise of share options		(754)	(1,564)
Net cash provided by financing activities		328,799	364,072
Net increase in cash, cash equivalents and restricted cash	[3]	214,708	141,379
Cash, cash equivalents and restricted cash at beginning of period	[3]	612,677	640,218
Cash, cash equivalents and restricted cash at end of period	[3]	$ 827,385	$ 781,597
[1]	Following the adoption of the amendments to ASC 230, we have made an accounting policy election to classify distributions received from equity method investees using the "cumulative earnings approach" and, as a result, certain of the dividends received have been retrospectively reclassified, where required, as cash inflows from investing activities for the six months ended June 30, 2017.
[2]	This relates to the cash reserves held by the Hilli Lessor VIE as of the date that we determined ourselves to be its primary beneficiary and thus required to consolidate the VIE. See note 8.
[3]	Following the adoption of the amendments to ASC 230, the statement of cash flows presents the change in the period in total cash, cash equivalents and restricted cash. These amendments have been applied retrospectively for the six months ended June 30, 2017.

UNAUDITED CONSOLIDATED STATEME6

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) Income	Accumulated Retained Earnings (Losses)	Total before Non-controlling Interest	Non-controlling Interest
Beginning balance at Dec. 31, 2016		$ 1,909,826	$ 101,081	$ (20,483)	$ 1,488,556	$ 200,000		$ (9,542)	$ 103,650	$ 1,863,262	$ 46,564
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		(123,720)							(139,651)	(139,651)	15,931
Dividends		(9,868)							(9,868)	(9,868)
Grant of share options		4,915			4,915					4,915
Other comprehensive income (see note 14)		1,632						1,632		1,632
Issuance of convertible bonds		39,861			39,861					39,861
Ending balance at Jun. 30, 2017		1,822,646	101,081	(20,483)	1,533,332	200,000		(7,910)	(45,869)	1,760,151	62,495
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 income (loss)		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 share options		7,214			7,214					7,214
Forfeiture of share options		(1,426)			(1,426)					(1,426)
Effect of consolidating Hilli Lessor VIE	[2]	28,702									28,702
Other comprehensive income (see note 14)		(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
[1]	Contributed Surplus is capital that can be returned to stockholders without the need to reduce share capital, thereby giving Golar greater flexibility when it comes to declaring dividends.
[2]	This relates to the reserves held by the Hilli Lessor VIE as of the date that we determined ourselves to be its primary beneficiary and thus required to consolidate the VIE. See note 8.

General

General	6 Months Ended
	Jun. 30, 2018
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, 2018 , our fleet comprises of 12 LNG carriers, one Floating Storage Regasification Unit (''FSRU'') and one Floating Liquefaction Natural Gas vessel ("FLNG"). We also operate, under management agreements, Golar LNG Partners LP's ("Golar Partners" or the "Partnership") fleet of 10 vessels and Golar Power Limited's ("Golar Power") fleet of two LNG carriers and one newbuilding commitment. Collectively with Golar Partners and Golar Power, our combined fleet is comprised of 18 LNG carriers, seven FSRUs and one FLNG. 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. FLNG Hilli In July 2014, we ordered our first FLNG based on the conversion of our existing LNG carrier, the Hilli Episeyo (the " Hilli "). The Hilli conversion completed in October 2017, and she arrived in Cameroon on November 20, 2017, where she underwent acceptance testing procedures. The Hilli has now completed her acceptance testing procedures, has been accepted under the Liquefaction Tolling Agreement ("LTA") with Perenco Cameroon S.A. ("Perenco") and Société Nationale des Hydrocarbures ("SNH") and is now in full commercial operation. The LTA with Perenco and SNH (together, the "Customer"), was executed on November 29, 2017 and considered legally effective on December 19, 2017 when all conditions precedent were met. Following the effectiveness of the LTA, a derivative asset of $79.6 million was initially recognized, representing the fair value of the estimated discounted cash flows of payments due to us as a result of the Brent Crude price moving above the contractual floor of $60.00 per barrel over the contract term. The derivative asset is subsequently remeasured to fair value at each balance sheet date. The fair value as of June 30, 2018 and December 31, 2017 was $203.0 million and $94.7 million , respectively (see note 15). This resulted in the recognition of a "Realized and unrealized gain on FLNG derivative instrument" of $108.3 million and $ nil for the six months ended June 30, 2018 and 2017, respectively, presented under "Other operating income" in our consolidated statements of income. The corresponding liability relating to the initial fair value of the FLNG derivative ("Day 1 gain") of $79.6 million was deferred and is being released to earnings on a straight-line basis over the term of the LTA, presented under the line item "Liquefaction services revenue" in the consolidated statements of income. Going concern The condensed consolidated financial statements have been prepared on a going concern basis. A pre-condition of the Golar Tundra lease financing with CMBL of $155.3 million (refer to note 8), which is secured on the vessel, is for the FSRU to be employed under an effective charter. Under the terms of our sale and lease back facility for the Golar Tundra , by virtue of our prior termination of the WAGL charter, we are required to find a replacement charter by June 30, 2019 or we could be required to refinance the FSRU. A similar pre-condition also applies to the Golar Seal lease financing with CCBFL of $143.8 million (refer to note 8), which is secured on the vessel, whereby the vessel is to be employed under an effective charter by December 31, 2018 or we could be required to refinance the LNG carrier. Accordingly, to address our anticipated working capital requirements over the next 12 months, in the event we are unable to secure a charter for the Golar Tundra or the Golar Seal , we are currently exploring our refinancing options, which may include seeking further extensions by the lenders of their deadlines for satisfaction of such. While we believe we will be able to obtain the necessary funds from these refinancings, we cannot be certain that the proposed new credit facilities will be executed in time or at all. However, we have a track record of successfully financing and refinancing our vessels, even in the absence of term charter coverage. In addition to vessel refinancings, if market and economic conditions are favorable, we may also consider further issuances of corporate debt or equity to increase liquidity. With respect to our Golar Power joint venture with Stonepeak, pursuant to the recent closing by CELSE (Golar Power’s affiliate in which it holds a 50% interest) of a $1.34 billion financing facility for the Sergipe Project which is partially drawn down, no further equity contributions are expected to be required from Golar Power in relation to the Sergipe Project. Our medium and long-term liquidity requirements are primarily for funding the investments for our conversion projects including investments into our potential joint venture, and repayment of long-term debt balances. Sources of funding for our medium and long-term liquidity requirements include new loans, refinancing of existing financing arrangements, public and private debt or equity offerings, and potential sales of our interests in our vessel owning subsidiaries operating under long-term charters (including additional sales of interests in Golar Hilli LLC ("Hilli LLC")).

Accounting Policies

Accounting Policies	6 Months Ended
	Jun. 30, 2018
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. The condensed consolidated financial statements do not include all of the disclosures required in the annual consolidated financial statements, and should be read in conjunction with our annual financial statements for the year ended December 31, 2017 . Significant accounting policies The accounting policies adopted in the preparation of the condensed consolidated financial statements for the six months ended June 30, 2018 are consistent with those followed in the preparation of our audited consolidated financial statements for the year ended December 31, 2017 , except for the following significant changes to our accounting policy "Revenue and related expense recognition" as a result of adopting the requirements of ASU 2014-09 "Revenue from Contracts with Customers (Topic 606)" (hereafter, ASC 606), for further changes, see note 3, and as a result of a change in presentation of expenses in the statements of income in quarter ended June 30, 2018 . Revenue and related expense recognition Time charter agreements Revenues include minimum lease payments under time charters and gross pool revenues. Revenues generated from time charters, which we classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is offhire, for example when the vessel is undergoing repairs. These expenses are recognized as incurred. Vessel operating expenses, which are recognized when incurred, include crewing, repairs and maintenance, insurance, stores, lube oils, communication expenses and third party management fees. Bunkers consumption represents mainly bunkers consumed during unemployment and off-hire. Liquefaction services revenue Liquefaction services revenue is generated from a LTA entered into with our customer. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. The liquefaction services capacity provided to our customer is considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. Contractual payment terms for liquefaction services is monthly in arrears, after services have been provided, generally resulting in the recognition of contract assets. Contract assets are regularly assessed for impairment. Contract liabilities arise when the customer makes payments in advance of receiving services. The term between when invoicing and when payment is due is not significant. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Management fees Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. Commercial and technical vessel-related services include vessel maintenance, providing vessel crew, making arrangements for vessel insurance, bunkering, provisions and stores, invoicing and collecting vessel hire. Corporate and administrative services include corporate services, group accounting, treasury, legal, tax, consultancy and other administrative services. These services are provided to our customers Golar Partners, Golar Power and OneLNG. Our contracts generally have an initial contract term of one year or less, after which the arrangement continues with a short notice period to end the contract, ranging from 30 days to 180 days. Our management services provided are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. Contractual payment terms for management fees generally allow for billing and payment in advance of services being provided. However, contract liabilities did not arise because there was no billing in recognition for services rendered in future periods at the reporting date. Contract assets arise when we render management services in advance of receiving payment from our customers. Contract assets are regularly assessed for impairment. The transaction price is generally considered variable consideration given the key driver of consideration is actual costs incurred in a given period, which varies each period according to activity levels. The entire amount of the transaction price is allocated to the single performance obligation identified. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount we have the right to invoice. Cool Pool Pool revenues and expenses under the Cool Pool arrangement have been accounted for in accordance with the guidance for collaborative arrangements. In relation to our vessels participating within the pool, voyage expenses and commissions from collaborative arrangements include an allocation of our net results from the pool to the other participants. Each participants' share of the net pool revenues is based on the number of pool points attributable to its vessels and the number of days such vessels participated in the pool. We have presented our share of the net income earned under the Cool Pool arrangement across a number of line items in the income statement. For net revenues and expenses incurred relating specifically to Golar’s vessels, and for which we are deemed the principal, these will be presented gross on the face of the income statement in the line items "Time and voyage charter revenues" and "Voyage, charterhire and commission expenses". For pool net revenues generated by the other participants in the pooling arrangement, these will be presented separately in revenue and expenses from collaborative arrangements. Refer to note 16 for an analysis of the income statement effect for the pooling arrangement. Project development expenses With effect from the quarter ended June 30, 2018 , we presented a new line item in operating expenses on the face of the statements of income. The new line item, "Project development expenses", includes the costs associated with pursuing future contracts and developing our pipeline of activities that have not met our internal threshold for capitalization. Previously, these costs were presented within "Administrative expenses" along with our general overhead costs. We believe that the introduction of this new line item in the statements of income provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods. The change in presentation for the six months ended June 30, 2018 is as follows: Six months ended June 30, 2017 (in thousands of $) As previously reported Adjustments decrease As adjusted Administrative expenses 22,546 (4,277 ) 18,269 Use of estimates The preparation of financial statements in accordance with United States Generally Accepted Accounting Principles ("US GAAP") requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. As of June 30, 2018 , 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-term and long-term debt, restricted cash and short-term deposits, non-controlling interests, interest income and interest expense. In consolidating these lessor VIEs, on a quarterly basis, we must make assumptions regarding (i) the debt amortization profile; (ii) the interest rate to be applied against the VIEs’ debt principal; and (iii) the VIE's application of cash receipts. Our estimates are therefore dependent upon the timeliness of receipt and accuracy of financial information provided by these lessor VIE entities. Upon receipt of the audited annual financial statements of the lessor VIEs, we will make a true-up adjustment for any material differences. In relation to the FLNG derivative (see note 1), 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 LTA. Significant inputs used in the valuation of the FLNG derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our FLNG derivative is recognized in each period in current earnings in "Realized and unrealized gain on FLNG derivative instrument". The realized and unrealized gain on FLNG derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2018 2017 Realized gain on FLNG derivative instrument 3,586 — Unrealized gain on FLNG derivative instrument 108,300 — 111,886 — For further information on the nature of this derivative, refer to note 15. The unrealized gain results from movement in oil prices above a contractual floor price over term of the LTA; the realized gain results from monthly billings above the base tolling fee under the LTA.

Recently Issued Accounting Stan

Recently Issued Accounting Standards	6 Months Ended
	Jun. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recently Issued Accounting Standards	RECENTLY ISSUED ACCOUNTING STANDARDS Adoption of new accounting standards In May 2014, the FASB issued ASC 606 and subsequent amendments. The standard provides a single, comprehensive revenue recognition model and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We adopted this guidance on January 1, 2018, under a modified retrospective approach - see note 5 for further details. The adoption of this guidance impacts presentation and disclosure of our management fee revenue only, there is no impact to recognition or measurement. In January 2016, the FASB issued ASU 2016-01 Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , which made targeted improvements to the recognition, measurement, presentation and disclosure of financial instruments. We adopted the amendments to this ASU on January 1, 2018 under a modified retrospective approach except for equity securities without a determinable fair value, for which a prospective approach is prescribed. The adoption of this ASU did not have a material impact on the consolidated financial statements. In August 2016, the FASB issued ASU 2016-15 Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments , which provides guidance on the disclosure and classification of certain items within the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows. In November 2016, the FASB issued ASU 2016-18 Statement of Cash Flows (Topic 230): Restricted Cash , which requires that restricted cash be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts presented on the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows and related disclosures. The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the six months ended June 30, 2017: Six months ended June 30, 2017 (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted OPERATING ACTIVITIES Restricted cash and short-term deposits (406 ) 406 — INVESTING ACTIVITIES Restricted cash and short-term deposits (6,544 ) 6,544 — FINANCING ACTIVITIES Restricted cash and short-term deposits (15,393 ) 15,393 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net increase in cash, cash equivalents and restricted cash 119,036 22,343 141,379 Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 343,226 438,371 781,597 In January 2017, the FASB issued ASU 2017-01 Business Combinations (Topic 805): Clarifying the Definition of a Business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. We adopted this ASU prospectively from January 1, 2018. As a result, this increases the likelihood that future vessel dropdowns may be considered the sale of an asset rather than a business. However, this will be dependent upon the facts and circumstances of each prospective transaction. There was no material impact on the adoption of this ASU on our consolidated financial statements and related disclosures. In February 2017, the FASB issued ASU 2017-05 Other Income - Gains and Losses from the Derecognition of Non-Financial Assets . This ASU clarifies the scope of guidance applicable to sales of non-financial assets and also provides guidance on partial sales of such assets. We adopted this ASU prospectively from January 1, 2018. We expect any gain or loss on sale from future dropdowns, accounted for as a disposal, will be recognized in full on the disposal date, however this will be dependent on the facts and circumstances of each prospective transaction. There was no material impact to our consolidated financial statements and related disclosures on adoption of this standard. Accounting pronouncements that have been issued but not adopted In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) and subsequent amendments. This standard requires a lessee to recognize right-of-use assets and lease liabilities on its balance sheet for all leases with terms longer than 12 months and introduces additional disclosure requirements. Lessors are required to classify leases as sales-type, finance or operating, with classification affecting the pattern of income recognition and provides guidance for sale and leaseback transactions. Classification for both lessees and lessors will be based on an assessment of whether risks and rewards as well as substantive control have been transferred through a lease contract. The standard will become effective on a modified retrospective basis for us on January 1, 2019. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. Due to the transition provisions for lessors, we expect the most significant impact of the adoption of this standard will be the recognition of lease assets and lease liabilities on our balance sheet for those leases where we are a lessee that are currently classified as operating leases. In June 2016, the FASB issued ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments which requires recognition and measurement of expected credit losses for financial assets and off balance sheet credit exposures. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics covering primarily minor corrections, clarifications and codification improvements. We are evaluating the impact of these amendments on our consolidated financial statements and related disclosures.

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION We are a marine LNG infrastructure provider and a project development company. We own and operate LNG carriers, a FLNG and FSRUs and provide these services under time charters under varying periods. As of June 30, 2018 , we have completed the commissioning of our first FLNG vessel and have entered the power market in an effort to become a midstream LNG solution provider. Our reportable segments consist of the primary services each provides. Although our segments are generally influenced by the same economic factors, each represents a distinct product in the LNG industry. Segment results are evaluated based on 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, 2018 , 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 has been accepted by the Customer under the LTA. In July 2016, we entered into an agreement with Schlumberger B.V. ("Schlumberger") to form OneLNG, a joint venture, with the intention to offer an integrated upstream and midstream solution for the development of low cost gas reserves to LNG. As a result we report the equity in net losses of OneLNG in the FLNG segment. In May 2018, it was decided that Golar and Schlumberger will wind down OneLNG and work on FLNG projects as required on a case-by-case basis. • Power – In July 2016, we entered into certain agreements forming a 50/50 joint venture, Golar Power, with private equity firm Stonepeak. Golar Power offers integrated LNG based downstream solutions, through the ownership and operation of FSRUs and associated terminal and power generation infrastructure. June 30, 2018 June 30, 2017 (3) (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 106,987 18,577 — — 125,564 53,518 — — — 53,518 Depreciation and amortization (32,775 ) (4,091 ) — — (36,866 ) (42,552 ) — — — (42,552 ) Other operating expenses (103,058 ) (12,172 ) — — (115,230 ) (76,100 ) (226 ) — — (76,326 ) Other operating gains and losses 10,000 101,366 — — 111,366 — — — — — Operating (loss) income (18,846 ) 103,680 — — 84,834 (65,134 ) (226 ) — — (65,360 ) Inter segment operating (loss) income (2) 205 — — (205 ) — 199 — — (199 ) — Segment operating (loss) income (18,641 ) 103,680 — (205 ) 84,834 (64,935 ) (226 ) — (199 ) (65,360 ) Equity in net earnings (losses) of affiliates 8,693 (2,047 ) (12,861 ) — (6,215 ) (2,606 ) (3,126 ) (7,461 ) — (13,193 ) Balance Sheet: June 30, 2018 December 31, 2017 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Total assets 2,882,837 2,056,768 258,690 (5,321 ) 5,192,974 3,025,244 1,515,463 228,696 (5,116 ) 4,764,287 Investment in affiliates 449,974 — 258,690 — 708,664 472,482 2,047 228,696 — 703,225 (1) Eliminations required for consolidation purposes. (2) Inter segment operating (loss) income relates to management fee revenues between the segments. (3) We no longer consider LNG trading a separate reportable segment. Given the previously reported segment information was immaterial for all periods presented, we have included these amounts within the vessel operations segment. Revenues from external customers During the six months ended June 30, 2018 , 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, 2018 and 2017 , 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 $) 2018 2017 Cool Pool (note 16) 83,959 74 % 39,444 90 % Perenco and SNH 18,577 16 % — — % An energy and logistics company 4,579 4 % 4,579 10 %

Revenue Revenue

Revenue Revenue	6 Months Ended
	Jun. 30, 2018
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, 2018 17,245 — Payments received for services billed (9,989 ) — Services provided and billed in current period 31,535 33,763 Payments received for services billed in current period (13,631 ) — Impairment (1,006 ) — Deferred commissioning period billing — (357 ) Closing balance on June 30, 2018 24,154 33,406 (1) Relates to management fee revenue and liquefaction services revenue, see a) and b) below. (2) Relates to liquefaction services revenue, see b) below. a) Management fee revenue: By virtue of an agreement to offset intercompany balances entered into between us and Golar Partners, of our total contract asset balances above: • $3.1 million is included in balance sheet line item "Amounts due from related parties" under current assets ( $7.2 million at December 31, 2017), and • $1.0 million is included in "Amounts due to related parties" under current liabilities ( $10.0 million at December 31, 2017). Refer to note 16 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 $) 2018 2017 Base tolling fee (1) 17,427 — Amortization of deferred commissioning period billing (2) 357 — Amortization of Day 1 gain (3) 841 — Other (50 ) — Total 18,577 — (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel (included in the balance sheets in line-items "Other current assets" and "Other non-current assets"), and at an increased rate when the oil price is greater than $60 per barrel (recognized as a derivative and included in the statements of income line-item "Realized and unrealized gain on FLNG derivative instrument", excluded from revenue and from the transaction price). (2) Customer billing during the commissioning period prior up 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 the balance sheet line-items "Other current liabilities" and "Other non-current liabilities") and recognized as liquefaction services revenue evenly over the contract term. (3) The Day 1 gain was established when the FLNG derivative asset was initially recognized in December 2017 for $79.6 million (recognized in balance sheet line-item "Other current liabilities" and "Other non-current liabilities"). This amount is amortized and recognized as liquefaction services revenue evenly over the contract term. We expect to recognize liquefaction services revenue related to the partially unsatisfied performance obligation at the reporting date evenly over the remaining contract term of less than eight years, including the components of transaction price described above.

Earnings (Loss) Per Share

Earnings (Loss) Per Share	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Earnings (Loss) Per Share	EARNINGS (LOSS) PER SHARE Basic earnings (loss) 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, 2018 2017 Net income (loss) attributable to Golar LNG Ltd stockholders - basic and diluted 15,317 (139,651 ) The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) Six months ended June 30, 2018 2017 Basic: Weighted average number of common shares outstanding 100,628 100,581 Dilutive: Dilutive impact of share options 100 — Weighted average number of common shares outstanding 100,728 100,581 Earnings (loss) per share are as follows: Six months ended June 30, 2018 2017 Basic $ 0.15 $ (1.39 ) Diluted $ 0.15 $ (1.39 ) For the six months ended June 30, 2018 and 2017 , convertible bonds have been excluded from the calculation of diluted EPS because the effect was anti-dilutive.

Other Financial Items

Other Financial Items	6 Months Ended
	Jun. 30, 2018
Other Income and Expenses [Abstract]
Other Financial Items	OTHER FINANCIAL ITEMS, NET Other financial items, net comprise of the following: (in thousands of $) Six months ended June 30, 2018 2017 Mark-to-market adjustment for interest rate swap derivatives 7,713 (603 ) Unrealized mark-to-market losses on Earn-Out Units (4,500 ) (500 ) Mark-to-market adjustment for equity derivatives (4,374 ) (4,323 ) Interest income/(expense) on undesignated interest rate swaps 2,596 (2,706 ) Foreign exchange loss on operations (618 ) (944 ) Amortization of debt guarantee 361 846 Financing arrangement fees and other costs (53 ) (239 ) Others (531 ) 541 594 (7,928 )

Variable Interest Entities ("VI

Variable Interest Entities ("VIE")	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities (VIE)	VARIABLE INTEREST ENTITIES ("VIE") As of June 30, 2018 and December 31, 2017 , we leased eight vessels from VIEs under finance leases, 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 China State Shipbuilding Corporation ("CSSC") entity. Each of the ICBCL, CMBL, CCBFL, COSCO and CSSC entities are wholly-owned, newly formed special purpose vehicles ("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, 2017 , 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, 2018 and December 31, 2017 , the respective vessels are reported under "Vessels and equipment, net" in our consolidated balance sheets. Hilli Lessor VIE In June 2018, we sold the Hilli to a CSSC entity and subsequently leased back the vessel on a bareboat charter for a term of ten years. We have options to repurchase the vessel throughout the charter term at fixed pre-determined amounts, commencing from the fifth year anniversary of the commencement of the bareboat charter, with an obligation to repurchase the vessel at the end of the ten year lease period. A summary of this sale and lease back arrangement, including repurchase options and obligations as of June 30, 2018 is provided below: Vessel Effective from Sales value (in $ millions) First repurchase option (in $ millions) Date of first repurchase option Repurchase obligation at end of lease term (in $ millions) End of lease term Hilli June 2018 1,200.0 633.2 June 2023 300.0 June 2028 A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of June 30, 2018 , are shown below: (in thousands of $) 2018 (1) 2019 2020 2021 2022 2023+ Golar Glacier 8,620 17,100 17,147 17,100 17,100 29,984 Golar Kelvin 8,620 17,100 17,147 17,100 17,100 32,795 Golar Snow 8,620 17,100 17,147 17,100 17,100 32,795 Golar Ice 8,620 17,100 17,147 17,100 17,100 35,700 Golar Tundra (2)(3) 11,445 21,910 20,833 19,739 18,695 47,532 Golar Seal (3) 7,513 15,193 15,151 15,151 15,151 45,495 Golar Crystal (2) 6,083 11,934 11,726 11,477 11,271 45,529 Hilli (2) 64,568 126,118 121,036 116,143 111,279 505,666 (1) For the six months ending December 31, 2018. (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. (3) The payment obligations relating to the Golar Tundra and Golar Seal above have been prepared on the assumption that we are able to secure a replacement charter for these two vessels, to ensure continuation of these financing arrangements. Refer to note 1 for further details. The assets and liabilities of these lessor VIEs that most significantly impact our consolidated balance sheet as of June 30, 2018 and December 31, 2017 , are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli June 30, 2018 December 31, 2017 Assets Total Total Restricted cash and short-term deposits 18,844 62,319 18,548 8 25,000 22,141 2,372 36,441 185,673 130,063 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 39,314 182,540 30,398 126,508 155,318 143,849 10,075 148,880 836,882 833,664 Long-term interest bearing debt - non-current portion (1) 117,841 — 127,189 — — — 89,246 779,400 1,113,676 252,691 157,155 182,540 157,587 126,508 155,318 143,849 99,321 928,280 1,950,558 1,086,355 (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 $19.1 million and $19.1 million for the six months ended June 30, 2018 and 2017 , respectively. The most significant impact of lessor VIE's cash flows on our unaudited consolidated statements of cash flows is net receipts of $864.7 million and $89.2 million in financing activities for the six months ended June 30, 2018 and 2017 , respectively.

Restricted cash and short term

Restricted cash and short term deposits	6 Months Ended
	Jun. 30, 2018
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, 2018 December 31, 2017 Restricted cash relating to the total return equity swap 62,547 58,351 Restricted cash in relation to the Hilli (1) 175,206 174,737 Restricted cash and short-term deposits held by lessor VIEs 185,673 130,063 Restricted cash relating to the $1.125 billion debt facility 27,384 33,752 Restricted cash relating to office lease 823 813 Bank guarantee 685 99 Total restricted cash and short-term deposits 452,318 397,815 Less: Amounts included in current restricted cash and short-term deposits (276,289 ) (222,265 ) Long-term restricted cash 176,029 175,550 (1) In November 2015, in connection with the issuance of a letter of credit by a financial institution to our project partner involved in the Hilli FLNG project, we were required to provide cash collateral to support the performance guarantee. The following table identifies the balance sheet line-items included in cash, cash equivalents and restricted cash presented in the consolidated statements of cash flows: (in thousands of $) June 30, 2018 December 31, 2017 June 30, 2017 December 31, 2016 Cash and cash equivalents 375,067 214,862 343,226 224,190 Restricted cash and short-term deposits (current portion) 276,289 222,265 205,227 183,693 Restricted cash (non-current portion) 176,029 175,550 233,144 232,335 827,385 612,677 781,597 640,218

Asset Under Development

Asset Under Development	6 Months Ended
	Jun. 30, 2018
Extractive Industries [Abstract]
Asset Under Development	ASSET UNDER DEVELOPMENT (in thousands of $) December 31, 2017 Purchase price installments 962,709 Interest costs capitalized 116,416 Other costs capitalized 98,364 1,177,489 In May 2014, we entered into agreements for the conversion of the Hilli to a FLNG vessel. The primary contract was entered into with Keppel Shipyard Limited ("Keppel"). The Hilli was delivered to Keppel in Singapore in September 2014 for the commencement of her conversion. As of June 30, 2018 the Hilli FLNG conversion and commissioning was completed, accordingly, we have reclassified the total balance to "Vessels and equipment, net" in our consolidated balance sheet as of June 30, 2018 .

Investments in Affiliates and J

Investments in Affiliates and Joint Ventures	6 Months Ended
	Jun. 30, 2018
Investments, Debt and Equity Securities [Abstract]
Investments in Affiliates and Joint Ventures	INVESTMENTS IN AFFILIATES AND JOINT VENTURES Six Months Ended June 30, (in thousands of $) 2018 2017 Share of net earnings (losses) in Golar Partners (1) 8,630 (2,906 ) Share of net loss in Golar Power (12,861 ) (7,461 ) Share of net loss in OneLNG (2,047 ) (3,126 ) Share of net earnings in Egyptian Company for Gas Services ("ECGS") 63 300 (6,215 ) (13,193 ) (1) For the six months ended June 30, 2017 , our share of net earnings (losses) in Golar Partners includes a non-cash loss on deemed disposal of $17.0 million , being the dilutive impact on our ownership interest due to further issuances of common units by Golar Partners in February 2017. The carrying amounts of our investments in our equity method investments as at June 30, 2018 and December 31, 2017 are as follows: (in thousands of $) June 30, 2018 December 31, 2017 Golar Partners 444,525 467,097 Golar Power 258,690 228,696 OneLNG (1) — 2,047 ECGS 5,449 5,385 Equity in net assets of affiliates 708,664 703,225 (1) The delays in finalizing a debt financing package for the Fortuna FLNG project, together with other capital and resource priorities, has resulted in a decision from Schlumberger to end their participation in the project. Golar and Schlumberger, as a result of this, plan to wind down OneLNG and work on FLNG projects as required on a case-by-case basis. As a result, we have written down our investment in OneLNG to $ nil at June 30, 2018 .

Other Non-Current Assets

Other Non-Current Assets	6 Months Ended
	Jun. 30, 2018
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, 2018 December 31, 2017 FLNG derivative (1) 203,000 94,700 Other non-current assets (2) 24,793 37,891 Mark-to-market interest rate swaps valuation 16,336 10,166 Investment in OLT Offshore LNG Toscana S.p.A (3) 7,347 7,347 Derivatives - other (4) — 7,400 251,476 157,504 (1) "FLNG derivative" refers to a derivative embedded in the Hilli LTA. See note 1 for further details. (2) "Other non-current assets" is mainly comprised of payments made relating to long lead items ordered in preparation for the conversion of the Gimi and the Gandria into FLNG vessels. As of June 30, 2018 and December 31, 2017 , the aggregate carrying value was $15.0 million and $31.0 million , respectively. The Gimi and the Gandria conversion contracts provide the flexibility wherein certain beneficial cancellation provisions exist which, if exercised prior to contract expiry, will allow termination of contracts and recovery of previous milestone payments, less cancellation fees. The Gimi contract will expire on December 30, 2018 and the Gandria contract will expire on December 31, 2018. (3) "Investment in OLT Offshore LNG Toscana S.p.A" ("OLT-O") refers to our investment in an Italian incorporated unlisted company which is involved in the construction, development, operation and maintenance of a FSRU terminal to be situated off the Livorno coast of Italy. In prior years, this investment was classified as a cost method investment. Following the adoption of ASU 2016-01, we have applied the measurement alternative for measuring equity investments without readily determinable fair values. As of June 30, 2018 and December 31, 2017 , our investment in OLT-O was $7.3 million , representing a 2.7% interest in OLT-O’s issued share capital. (4) "Derivatives - other" refers to the Earn-Out Units issuable to us in connection with the IDR Reset transaction with Golar Partners in October 2016.

Debt

Debt	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Debt	DEBT As of June 30, 2018 and December 31, 2017 , our debt was as follows: (in thousands of $) June 30, 2018 December 31, 2017 Golar Arctic facility 61,950 65,600 Golar Viking facility 49,479 52,083 2017 convertible bonds 346,698 340,173 Margin loan (1) 98,252 119,125 FLNG Hilli facility (2) — 525,000 Hilli shareholder loans 49,066 49,066 $1.125 billion facility 184,590 195,449 ICBCL VIE loans (3) 625,665 641,936 CCBFL VIE loan (3) 143,849 143,849 CMBL VIE loan (3) 155,317 198,613 COSCO Shipping VIE loan (3)(4) 100,022 104,006 CSSC VIE loan (2)(3) 928,280 — Total debt 2,743,168 2,434,900 Less: Deferred finance charges, net (18,483 ) (24,053 ) Total debt, net of deferred financing costs 2,724,685 2,410,847 (1) During July 2018, amendments to the existing margin loan facility, secured by units in Golar Partners, were completed. Although most of the existing terms remain substantially unchanged, the facility will no longer amortize. Subject to the satisfaction of certain covenants, no further principal repayments will be required ahead of maturity in March 2020. (2) In June 2018, we repaid $640.0 million on the pre-delivery credit facility and drew down $960.0 million on the post-acceptance sale and leaseback financing in relation to the FLNG Hilli facility. The sale and leaseback arrangement is provided by a related party of CSSC. (3) See note 8. (4) In April 2018, the SPV, Oriental Fleet LNG 01 Limited, which owns the Golar Crystal , entered into a long-term loan facility for $101.0 million . The loan facility is provided by a related party of COSCO Shipping. The loan facility is denominated in USD, is a 10 year loan, limited to the term of the bareboat charter, bears interest at LIBOR plus a margin and is repayable in monthly installments with a balloon payment on maturity. At June 30, 2018 , our debt can be broken down as follows: Golar debt VIE debt (1) Total debt (in thousands of $) Current portion of long-term debt and short-term debt 31,843 836,882 868,725 Long-term debt 742,284 1,113,676 1,855,960 Total 774,127 1,950,558 2,724,685 (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 8). CSSC VIE loan In June 2018, we repaid $640.0 million on the pre-delivery credit facility and entered into a sale and leaseback transaction pursuant to which we sold the Hilli to a CSSC entity ("Hilli Lessor VIE"), and leased back the vessel under a bareboat charter for a monthly hire rate. As discussed in note 8, while we have no control over the funding arrangements of Hilli Lessor VIE, we consider ourselves to be the primary beneficiary and therefore are required to consolidate the Hilli Lessor VIE’s funding arrangements into our financial statements. Accordingly, in June 2018, Hilli Lessor VIE, which is the legal owner of the Hilli , entered into a secured financing agreement for $840.0 million . This loan facility is a 10 year non-recourse loan denominated in USD, bears interest at LIBOR plus a margin and is repayable in quarterly installments with a balloon payment on maturity. In addition to this facility, Hilli Lessor VIE entered into an internal loan with CSSC for $120.0 million . This loan bears no interest and is repayable on demand.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	6 Months Ended
	Jun. 30, 2018
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, 2016 (12,956 ) 3,414 (9,542 ) Other comprehensive income — 1,632 1,632 Balance at June 30, 2017 (12,956 ) 5,046 (7,910 ) 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 )

Financial Instruments

Financial Instruments	6 Months Ended
	Jun. 30, 2018
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, 2018 and December 31, 2017 are as follows: June 30, 2018 December 31, 2017 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents Level 1 375,067 375,067 214,862 214,862 Restricted cash and short-term deposits Level 1 452,318 452,318 397,815 397,815 Current portion of long-term debt and short-term debt (1)(2) Level 2 871,507 871,507 1,393,229 1,393,229 Long-term debt - convertible bonds (2) Level 2 346,698 437,063 340,173 430,361 Long-term debt (2) Level 2 1,524,963 1,524,963 701,498 701,498 Derivatives: FLNG derivative (3)(7) Level 2 203,000 203,000 94,700 94,700 Interest rate swaps asset (3)(4) Level 2 17,879 17,879 10,166 10,166 Foreign exchange swaps asset (3) Level 2 35 35 51 51 Foreign exchange swaps liability (3) Level 2 573 573 223 223 Total return equity swap liability (3)(4)(5) Level 2 44,516 44,516 40,141 40,141 Earn-Out Units asset (6) Level 2 2,900 2,900 7,400 7,400 (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 $ 18.5 million and $ 24.1 million at June 30, 2018 and December 31, 2017 , respectively. (3) Derivative liabilities are captured within other current liabilities and derivative assets are generally captured within other 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 Earn-Out Units are issuable to Golar in connection with the IDR Reset transaction between Golar and Golar Partners in October 2016. (7) The fair value of the FLNG derivative 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 FLNG derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. As of June 30, 2018 , 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 1,250,000 2018 to 2021 1.13% to 1.94% 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, 2018 and December 31, 2017 would be adjusted as detailed in the following table: June 30, 2018 December 31, 2017 (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 17,879 — 17,879 10,166 — 10,166 The total return equity swap has a credit arrangement that requires us to provide cash collateral equaling 20% of the initial purchase price and to subsequently post additional cash collateral that corresponds to any unrealized loss. As at June 30, 2018 , cash collateral amounting to $62.5 million has been provided.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2018
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, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue (a) 3,877 2,571 Ship management fees revenue (b) 2,600 2,138 Charterhire expense (c) — (9,089 ) Interest expense on deposits payable (d) (4,484 ) (1,404 ) Total 1,993 (5,784 ) Payables: The balances with Golar Partners and its subsidiaries as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Deposit payable (d) (177,247 ) (177,247 ) Methane Princess security lease deposit movement (e) (3,143 ) (3,464 ) Trading balances owing to Golar Partners and affiliates (f) (7,040 ) (4,144 ) Total (187,430 ) (184,855 ) 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) Charterhire expenses - For the six months ended June 30, 2017 , this consists of charterhire expenses that we incurred for the charter back from Golar Partners of the Golar Grand , less any time charter revenues that Golar Partners generated through subleasing the Golar Grand from Golar during the period . On November 1, 2017, the Golar Grand arrangement concluded. d) Interest expense on deposits payable Expense under Tundra Letter Agreement - In May 2016, we completed the Golar Tundra Sale and received a total cash consideration of $107.2 million . We agreed to pay Golar Partners a daily fee plus operating expenses for the right to use the Golar Tundra from the date the Golar Tundra Sale was closed, until the date that the vessel would commence operations under the Golar Tundra Time Charter. In return, Golar Partners agreed to remit to us any hire income received with respect to the Golar Tundra during that period. It was further agreed that, if for any reason the Golar Tundra Time Charter had not commenced by the 12 month anniversary of the closing of the Golar Tundra Sale, Golar Partners had the right to require that we repurchase the shares of Tundra Corp at a price equal to the purchase price. Accordingly, by virtue of the put option, which was exercised by Golar Partners in May 2017, we continued to consolidate the Golar Tundra for the periods whilst the put option remained in place, thus we have accounted for $nil and $1.4 million as interest expense for the six months ended June 30, 2018 and 2017, respectively. Deferred purchase price - In May 2017, the Golar Tundra had not commenced her charter and, accordingly, Golar Partners elected to exercise the Tundra Put Right to require us to repurchase Tundra Corp at a price equal to the original purchase price. In connection with Golar Partners exercising the Tundra Put Right, we and Golar Partners entered into an agreement pursuant to which we agreed to purchase Tundra Corp from Golar Partners on the date of the closing of the Tundra Put Sale (the "Put Sale Closing Date") in return we will be required to pay an amount equal to $107.2 million (the "Deferred Purchase Price") plus an additional amount equal to 5% per annum of the Deferred Purchase Price (the "Additional Amount"). The Deferred Purchase Price and the Additional Amount shall be due and payable by us on the date of the closing of the Hilli Disposal (see below). We agreed to accept the Deferred Purchase Price and the Additional Amount in lieu of a cash receipt on the Put Sale Closing Date in return we have provided Golar Partners with an option (which Golar Partners have exercised) to purchase an interest in Hilli Corp. We have accounted for $2.7 million and nil as interest expense for the six months ended June 30, 2018 and 2017, respectively, in relation to the Deferred Purchase Price. Deposit received from Golar Partners - On August 15, 2017, we entered into a purchase and sale agreement (the "Hilli Sale Agreement") with Golar Partners for the disposal (the "Hilli Disposal") from Golar and affiliates of Keppel and Black & Veatch Corporation of common units (the "Disposal Interests") in Hilli LLC. On the closing date of the Hilli Disposal, Hilli LLC will indirectly (through its subsidiary) be the disponent owner of the Hilli . The Disposal Interests represent the equivalent of 50% of the two liquefaction trains, out of a total of four , that are contracted to Perenco and SNH under an eight -year LTA. The sale price for the Disposal Interests is $658 million less 50% of the net lease obligations under the financing facility for the Hilli (the "Hilli Facility") on closing date, plus post-closing purchase price adjustments. Concurrently with the execution of the Hilli Sale Agreement, we received a further $70 million deposit from Golar Partners, upon which we pay interest at a rate of 5% per annum. We have accounted for $1.8 million and $nil as interest expense for the six months ended June 30, 2018 and 2017, respectively, in relation to the $70 million deposit from Golar Partners. On June 12, 2018, we concluded the Hilli Disposal with Golar Partners, accordingly we applied the Deferred Purchase Price as well as the deposit received from Golar Partners against the disposal. 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. f) 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 in respect of disposals to the Partnership, as well as charterhire expenses. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Partners and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. They primarily relate to recharges for trading expenses paid on behalf of Golar Partners, including ship management and administrative service fees due to us. g) Distributions from Golar Partners - During the six months ended June 30, 2018 and June 30, 2017, we received total distributions from Golar Partners of $26.2 million and $25.7 million , respectively in respect of the common units and general partner units owned by us. b) Transactions with Golar Power and affiliates: Net revenues: The transactions with Golar Power and its affiliates for the six months ended June 30, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue 2,457 1,819 Ship management fees income 700 278 Debt guarantee compensation (a) 361 402 Other (247 ) — Total 3,271 2,499 Payables: The balances with Golar Power and its affiliates as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Trading balances due to Golar Power and affiliates (b) (6,803 ) (935 ) Total (6,803 ) (935 ) 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 $0.4 million and $0.4 million income for the six months ended June 30, 2018 and 2017 , 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. c) Transactions with OneLNG and subsidiaries: Net revenues: The transactions with OneLNG and its subsidiaries for the six months ended June 30, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue 1,399 2,708 Total 1,399 2,708 Receivables: The balances with OneLNG and its subsidiaries as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Trading balances due from OneLNG (a) 10,912 7,898 Total 10,912 7,898 a) Trading balances - Receivables and payables with One LNG and its subsidiaries are comprised primarily of unpaid management fees, charterhire expenses, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from OneLNG are unsecured, interest-free and intended to be settled in the ordinary course of business. Subsequent to the decision to dissolve OneLNG, we have written off $10.0 million of the trading balance with OneLNG as we deem it to be no longer recoverable. The trade receivables of $10.9 million is net of this provision. 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 $) 2018 2017 Time and voyage charter revenues 64,605 27,705 Time charter revenues - collaborative arrangement 19,353 11,739 Voyage, charterhire and commission expenses (8,600 ) (82 ) Voyage, charterhire and commission expenses - collaborative arrangement (30,897 ) (12,772 ) Net income from the Cool Pool 44,461 26,590 Receivables from other related parties: (in thousands of $) June 30, 2018 December 31, 2017 Cool Pool (a) 10,514 14,004 10,514 14,004 a) Trade accounts receivable includes amounts due from the Cool Pool arising from our collaborative arrangement, amounting to $10.5 million as of June 30, 2018 (December 31, 2017: $14.0 million ). From our participation in the Cool Pool, we recognized net income of $44.5 million and $26.6 million for the six months ended June 30, 2018 and 2017 , respectively.

Other Commitments and Contingen

Other Commitments and Contingencies	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Other Commitments and Contingencies	OTHER COMMITMENTS AND CONTINGENCIES Assets pledged (in thousands of $) June 30, 2018 December 31, 2017 Book value of vessels secured against long-term loans 3,299,901 2,032,747 As at June 30, 2018 , 21,226,586 Golar Partners common units were pledged as security for the obligations under the Margin Loan Facility. See note 13. UK tax lease benefits As described under note 31 in our audited consolidated financial statements filed with our Annual Report on Form 20-F for the year ended December 31, 2017 , during 2003 we entered into six UK tax leases. Under the terms of the leasing arrangements, the benefits are derived primarily from the tax depreciation assumed to be available to the lessors as a result of their investment in the vessels. As is typical in these leasing arrangements, as the lessee we are obligated to maintain the lessor’s after-tax margin. Accordingly, in the event of any adverse tax changes or a successful challenge by the UK Tax Authorities (''HMRC'') with regard to the initial tax basis of the transactions, or in relation to the 2010 lease restructurings, or in the event of an early termination of the Methane Princess lease, we may be required to make additional payments principally to the UK vessel lessor, which could adversely affect our earnings or financial position. We would be required to return all, or a portion of, or in certain circumstances significantly more than, the upfront cash benefits that we received in respect of our lease financing transactions, including the 2010 restructurings and subsequent termination transactions. The gross cash benefit we received upfront on these leases amounted to approximately £41 million British Pounds (before deduction of fees). Of these six leases we have since terminated five , with one lease remaining, being that of the Methane Princess lease. Pursuant to the deconsolidation of Golar Partners in 2012, Golar Partners is no longer considered a controlled entity but an affiliate and therefore as at June 30, 2018 , the capital lease obligation relating to this remaining UK tax lease is not included on our consolidated balance sheet. However, under the indemnity provisions of the Omnibus Agreement or the respective share purchase agreements, we have agreed to indemnify Golar Partners in the event of any tax liabilities in excess of scheduled or final scheduled amounts arising from the Methane Princess leasing arrangements and termination thereof. HMRC has been challenging the use of similar lease structures and has been engaged in litigation of a test case for some years. In August 2015, following an appeal to the Court of Appeal by the HMRC which set aside previous judgments in favor of the tax payer, the First Tier Tribunal (UK court) ruled in favor of HMRC. The tax payer in this particular ruling has the election to appeal the courts’ decision, but no appeal has been filed. The judgments of the First Tier Tribunal do not create binding precedent for other UK court decisions and therefore the ruling in favor of HMRC is not binding in the context of our structures. Further, we consider there are differences in the fact pattern and structure between this case and our 2003 leasing arrangements and therefore is not necessarily indicative of any outcome should HMRC challenge us and we remain confident that our fact pattern is sufficiently different to succeed if we are challenged by HMRC. HMRC have written to our lessor to indicate that they believe our lease may be similar to the case noted above. We have reviewed the details of the case and the basis of the judgment with our legal and tax advisers to ascertain what impact, if any, the judgment may have on us and the possible range of exposure has been estimated at approximately £ nil to £112 million British Pounds. We are currently in conversation with HMRC on this matter, presenting the factual background of our position. 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, 2018 , we had a commitment to pay $1.0 million to a third party, contingent upon the conclusion of a material commercial business transaction by ECGS as consideration for work performed in connection with the setting up and incorporation of ECGS. We are party to a shareholders’ agreement with a consortium of investors to fund the development of pipeline infrastructure and a FSRU which are intended to supply two power plants in the Ivory Coast. The project is currently in the initial design phase, with final investment decision ("FID") currently expected to be taken in the second half of 2018. Negotiations are underway with third party lenders for the financing of construction costs in the event a positive investment decision is made. During the initial phase of the project, our remaining contractual commitments for this project are estimated to be in the region of €0.5 million . In the event a positive FID is taken on the project, this could increase up to approximately €15 million . This figure is dependent upon a variety of factors such as whether third party financing is obtained for a portion of the construction costs. The timing of this range of payments is dependent on whether and when FID is made, progress of negotiations with lenders for non-investor financing, and the progress of eventual construction work. The nature of payments to the project could be made in a combination of capital contributions or interest-bearing shareholder loans.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Dividends On August 23, 2018, we declared a dividend of $0.125 per share in respect of the quarter ended June 30, 2018 to holders of record on September 6, 2018, which will be paid on or about October 3, 2018. Hilli disposal to Golar Partners The drop down of 50% of the common units in Hilli LLC to Golar Partners under the terms of the Hilli Sale Agreement was concluded on July 12, 2018. Margin loan During July 2018, amendments to the existing margin loan facility, secured by units in Golar Partners, were completed. Although most of the existing terms remain substantially unchanged, the facility will no longer amortize. Previously the dividend cash received from the pledged Partnership shares was first used to service the interest on the loan, any excess cash was then used to prepay a portion of the principal. Under the modified agreement, any excess cash after servicing the interest will be returned to Golar. Subject to the satisfaction of certain covenants, no further principal repayments will be required ahead of loan maturity in March 2020. Hilli LLC Limited Liability Company Agreement In connection with the closing of the Hilli Disposal, Golar Partners has agreed to provide a several guarantee of 50% of the indebtedness of Hilli Corp under the Hilli Facility.

Accounting Policies (Policies)

Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of accounting	Basis of accounting The condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States. The condensed consolidated financial statements do not include all of the disclosures required in the annual consolidated financial statements, and should be read in conjunction with our annual financial statements for the year ended December 31, 2017 .
Use of estimates	Use of estimates The preparation of financial statements in accordance with United States Generally Accepted Accounting Principles ("US GAAP") requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. As of June 30, 2018 , 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-term and long-term debt, restricted cash and short-term deposits, non-controlling interests, interest income and interest expense. In consolidating these lessor VIEs, on a quarterly basis, we must make assumptions regarding (i) the debt amortization profile; (ii) the interest rate to be applied against the VIEs’ debt principal; and (iii) the VIE's application of cash receipts. Our estimates are therefore dependent upon the timeliness of receipt and accuracy of financial information provided by these lessor VIE entities. Upon receipt of the audited annual financial statements of the lessor VIEs, we will make a true-up adjustment for any material differences. In relation to the FLNG derivative (see note 1), 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 LTA. Significant inputs used in the valuation of the FLNG derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets. The changes in fair value of our FLNG derivative is recognized in each period in current earnings in "Realized and unrealized gain on FLNG derivative instrument". The realized and unrealized gain on FLNG derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2018 2017 Realized gain on FLNG derivative instrument 3,586 — Unrealized gain on FLNG derivative instrument 108,300 — 111,886 — For further information on the nature of this derivative, refer to note 15. The unrealized gain results from movement in oil prices above a contractual floor price over term of the LTA; the realized gain results from monthly billings above the base tolling fee under the LTA.
Adoption of new accounting standards, Accounting pronouncements to be adopted	Significant accounting policies The accounting policies adopted in the preparation of the condensed consolidated financial statements for the six months ended June 30, 2018 are consistent with those followed in the preparation of our audited consolidated financial statements for the year ended December 31, 2017 , except for the following significant changes to our accounting policy "Revenue and related expense recognition" as a result of adopting the requirements of ASU 2014-09 "Revenue from Contracts with Customers (Topic 606)" (hereafter, ASC 606), for further changes, see note 3, and as a result of a change in presentation of expenses in the statements of income in quarter ended June 30, 2018 . Revenue and related expense recognition Time charter agreements Revenues include minimum lease payments under time charters and gross pool revenues. Revenues generated from time charters, which we classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is offhire, for example when the vessel is undergoing repairs. These expenses are recognized as incurred. Vessel operating expenses, which are recognized when incurred, include crewing, repairs and maintenance, insurance, stores, lube oils, communication expenses and third party management fees. Bunkers consumption represents mainly bunkers consumed during unemployment and off-hire. Liquefaction services revenue Liquefaction services revenue is generated from a LTA entered into with our customer. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. The liquefaction services capacity provided to our customer is considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. Contractual payment terms for liquefaction services is monthly in arrears, after services have been provided, generally resulting in the recognition of contract assets. Contract assets are regularly assessed for impairment. Contract liabilities arise when the customer makes payments in advance of receiving services. The term between when invoicing and when payment is due is not significant. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Management fees Management fees are generated from commercial and technical vessel-related services and corporate and administrative services. Commercial and technical vessel-related services include vessel maintenance, providing vessel crew, making arrangements for vessel insurance, bunkering, provisions and stores, invoicing and collecting vessel hire. Corporate and administrative services include corporate services, group accounting, treasury, legal, tax, consultancy and other administrative services. These services are provided to our customers Golar Partners, Golar Power and OneLNG. Our contracts generally have an initial contract term of one year or less, after which the arrangement continues with a short notice period to end the contract, ranging from 30 days to 180 days. Our management services provided are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. Contractual payment terms for management fees generally allow for billing and payment in advance of services being provided. However, contract liabilities did not arise because there was no billing in recognition for services rendered in future periods at the reporting date. Contract assets arise when we render management services in advance of receiving payment from our customers. Contract assets are regularly assessed for impairment. The transaction price is generally considered variable consideration given the key driver of consideration is actual costs incurred in a given period, which varies each period according to activity levels. The entire amount of the transaction price is allocated to the single performance obligation identified. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount we have the right to invoice. Cool Pool Pool revenues and expenses under the Cool Pool arrangement have been accounted for in accordance with the guidance for collaborative arrangements. In relation to our vessels participating within the pool, voyage expenses and commissions from collaborative arrangements include an allocation of our net results from the pool to the other participants. Each participants' share of the net pool revenues is based on the number of pool points attributable to its vessels and the number of days such vessels participated in the pool. We have presented our share of the net income earned under the Cool Pool arrangement across a number of line items in the income statement. For net revenues and expenses incurred relating specifically to Golar’s vessels, and for which we are deemed the principal, these will be presented gross on the face of the income statement in the line items "Time and voyage charter revenues" and "Voyage, charterhire and commission expenses". For pool net revenues generated by the other participants in the pooling arrangement, these will be presented separately in revenue and expenses from collaborative arrangements. Refer to note 16 for an analysis of the income statement effect for the pooling arrangement. Project development expenses With effect from the quarter ended June 30, 2018 , we presented a new line item in operating expenses on the face of the statements of income. The new line item, "Project development expenses", includes the costs associated with pursuing future contracts and developing our pipeline of activities that have not met our internal threshold for capitalization. Previously, these costs were presented within "Administrative expenses" along with our general overhead costs. We believe that the introduction of this new line item in the statements of income provides users of our financial statements greater transparency over a key element of our business. This presentation change has been retrospectively restated in prior periods. Adoption of new accounting standards In May 2014, the FASB issued ASC 606 and subsequent amendments. The standard provides a single, comprehensive revenue recognition model and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. We adopted this guidance on January 1, 2018, under a modified retrospective approach - see note 5 for further details. The adoption of this guidance impacts presentation and disclosure of our management fee revenue only, there is no impact to recognition or measurement. In January 2016, the FASB issued ASU 2016-01 Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , which made targeted improvements to the recognition, measurement, presentation and disclosure of financial instruments. We adopted the amendments to this ASU on January 1, 2018 under a modified retrospective approach except for equity securities without a determinable fair value, for which a prospective approach is prescribed. The adoption of this ASU did not have a material impact on the consolidated financial statements. In August 2016, the FASB issued ASU 2016-15 Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments , which provides guidance on the disclosure and classification of certain items within the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows. In November 2016, the FASB issued ASU 2016-18 Statement of Cash Flows (Topic 230): Restricted Cash , which requires that restricted cash be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts presented on the statements of cash flows. We adopted this ASU on January 1, 2018 under a retrospective approach, resulting in presentational changes to our consolidated statements of cash flows and related disclosures. The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the six months ended June 30, 2017: Six months ended June 30, 2017 (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted OPERATING ACTIVITIES Restricted cash and short-term deposits (406 ) 406 — INVESTING ACTIVITIES Restricted cash and short-term deposits (6,544 ) 6,544 — FINANCING ACTIVITIES Restricted cash and short-term deposits (15,393 ) 15,393 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net increase in cash, cash equivalents and restricted cash 119,036 22,343 141,379 Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 343,226 438,371 781,597 In January 2017, the FASB issued ASU 2017-01 Business Combinations (Topic 805): Clarifying the Definition of a Business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. We adopted this ASU prospectively from January 1, 2018. As a result, this increases the likelihood that future vessel dropdowns may be considered the sale of an asset rather than a business. However, this will be dependent upon the facts and circumstances of each prospective transaction. There was no material impact on the adoption of this ASU on our consolidated financial statements and related disclosures. In February 2017, the FASB issued ASU 2017-05 Other Income - Gains and Losses from the Derecognition of Non-Financial Assets . This ASU clarifies the scope of guidance applicable to sales of non-financial assets and also provides guidance on partial sales of such assets. We adopted this ASU prospectively from January 1, 2018. We expect any gain or loss on sale from future dropdowns, accounted for as a disposal, will be recognized in full on the disposal date, however this will be dependent on the facts and circumstances of each prospective transaction. There was no material impact to our consolidated financial statements and related disclosures on adoption of this standard. Accounting pronouncements that have been issued but not adopted In February 2016, the FASB issued ASU 2016-02 Leases (Topic 842) and subsequent amendments. This standard requires a lessee to recognize right-of-use assets and lease liabilities on its balance sheet for all leases with terms longer than 12 months and introduces additional disclosure requirements. Lessors are required to classify leases as sales-type, finance or operating, with classification affecting the pattern of income recognition and provides guidance for sale and leaseback transactions. Classification for both lessees and lessors will be based on an assessment of whether risks and rewards as well as substantive control have been transferred through a lease contract. The standard will become effective on a modified retrospective basis for us on January 1, 2019. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. Due to the transition provisions for lessors, we expect the most significant impact of the adoption of this standard will be the recognition of lease assets and lease liabilities on our balance sheet for those leases where we are a lessee that are currently classified as operating leases. In June 2016, the FASB issued ASU 2016-13 Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments which requires recognition and measurement of expected credit losses for financial assets and off balance sheet credit exposures. The guidance is effective on a modified retrospective basis for us on January 1, 2020 with early adoption permitted. We are evaluating the impact of this standard on our consolidated financial statements and related disclosures. In July 2018, the FASB issued ASU 2018-09 Codification improvements . The amendments in this ASU cover a wide range of topics covering primarily minor corrections, clarifications and codification improvements. We are evaluating the impact of these amendments on our consolidated financial statements and related disclosures.

Accounting Policies (Tables)

Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The change in presentation for the six months ended June 30, 2018 is as follows: Six months ended June 30, 2017 (in thousands of $) As previously reported Adjustments decrease As adjusted Administrative expenses 22,546 (4,277 ) 18,269 The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the six months ended June 30, 2017: Six months ended June 30, 2017 (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted OPERATING ACTIVITIES Restricted cash and short-term deposits (406 ) 406 — INVESTING ACTIVITIES Restricted cash and short-term deposits (6,544 ) 6,544 — FINANCING ACTIVITIES Restricted cash and short-term deposits (15,393 ) 15,393 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net increase in cash, cash equivalents and restricted cash 119,036 22,343 141,379 Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 343,226 438,371 781,597
Schedule of Price Risk Derivatives	The realized and unrealized gain on FLNG derivative instrument is as follows: (in thousands of $) Six months ended June 30, 2018 2017 Realized gain on FLNG derivative instrument 3,586 — Unrealized gain on FLNG derivative instrument 108,300 — 111,886 —

Recently Issued Accounting St27

Recently Issued Accounting Standards Recently Issued Accounting Standards (Tables)	6 Months Ended
	Jun. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The change in presentation for the six months ended June 30, 2018 is as follows: Six months ended June 30, 2017 (in thousands of $) As previously reported Adjustments decrease As adjusted Administrative expenses 22,546 (4,277 ) 18,269 The adoption changed how restricted cash is reported in the consolidated statements of cash flows as follows for the six months ended June 30, 2017: Six months ended June 30, 2017 (in thousands of $) Cash flow line item As previously reported Adjustments decrease As adjusted OPERATING ACTIVITIES Restricted cash and short-term deposits (406 ) 406 — INVESTING ACTIVITIES Restricted cash and short-term deposits (6,544 ) 6,544 — FINANCING ACTIVITIES Restricted cash and short-term deposits (15,393 ) 15,393 — As a result of the above changes, the following subtotals as retrospectively restated are as follows: Net increase in cash, cash equivalents and restricted cash 119,036 22,343 141,379 Cash, cash equivalents and restricted cash at beginning of period 224,190 416,028 640,218 Cash, cash equivalents and restricted cash at end of period 343,226 438,371 781,597

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	June 30, 2018 June 30, 2017 (3) (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Statement of Operations: Total operating revenues 106,987 18,577 — — 125,564 53,518 — — — 53,518 Depreciation and amortization (32,775 ) (4,091 ) — — (36,866 ) (42,552 ) — — — (42,552 ) Other operating expenses (103,058 ) (12,172 ) — — (115,230 ) (76,100 ) (226 ) — — (76,326 ) Other operating gains and losses 10,000 101,366 — — 111,366 — — — — — Operating (loss) income (18,846 ) 103,680 — — 84,834 (65,134 ) (226 ) — — (65,360 ) Inter segment operating (loss) income (2) 205 — — (205 ) — 199 — — (199 ) — Segment operating (loss) income (18,641 ) 103,680 — (205 ) 84,834 (64,935 ) (226 ) — (199 ) (65,360 ) Equity in net earnings (losses) of affiliates 8,693 (2,047 ) (12,861 ) — (6,215 ) (2,606 ) (3,126 ) (7,461 ) — (13,193 ) Balance Sheet: June 30, 2018 December 31, 2017 (in thousands of $) Vessel operations FLNG Power Other (1) Total Vessel operations FLNG Power Other (1) Total Total assets 2,882,837 2,056,768 258,690 (5,321 ) 5,192,974 3,025,244 1,515,463 228,696 (5,116 ) 4,764,287 Investment in affiliates 449,974 — 258,690 — 708,664 472,482 2,047 228,696 — 703,225 (1) Eliminations required for consolidation purposes. (2) Inter segment operating (loss) income relates to management fee revenues between the segments. (3) We no longer consider LNG trading a separate reportable segment. Given the previously reported segment information was immaterial for all periods presented, we have included these amounts within the vessel operations segment.
Schedules of Concentration of Risk, by Risk Factor	For the six months ended June 30, 2018 and 2017 , 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 $) 2018 2017 Cool Pool (note 16) 83,959 74 % 39,444 90 % Perenco and SNH 18,577 16 % — — % An energy and logistics company 4,579 4 % 4,579 10 %

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2018 17,245 — Payments received for services billed (9,989 ) — Services provided and billed in current period 31,535 33,763 Payments received for services billed in current period (13,631 ) — Impairment (1,006 ) — Deferred commissioning period billing — (357 ) Closing balance on June 30, 2018 24,154 33,406 (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 $) 2018 2017 Base tolling fee (1) 17,427 — Amortization of deferred commissioning period billing (2) 357 — Amortization of Day 1 gain (3) 841 — Other (50 ) — Total 18,577 — (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel (included in the balance sheets in line-items "Other current assets" and "Other non-current assets"), and at an increased rate when the oil price is greater than $60 per barrel (recognized as a derivative and included in the statements of income line-item "Realized and unrealized gain on FLNG derivative instrument", excluded from revenue and from the transaction price). (2) Customer billing during the commissioning period prior up 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 the balance sheet line-items "Other current liabilities" and "Other non-current liabilities") and recognized as liquefaction services revenue evenly over the contract term. (3) The Day 1 gain was established when the FLNG derivative asset was initially recognized in December 2017 for $79.6 million (recognized in balance sheet line-item "Other current liabilities" and "Other non-current liabilities"). This amount is amortized and recognized as liquefaction services revenue evenly over the contract term.

(Losses) Earnings Per Share (Ta

(Losses) Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2018 2017 Net income (loss) attributable to Golar LNG Ltd stockholders - basic and diluted 15,317 (139,651 ) The components of the denominator for the calculation of basic and diluted EPS are as follows: (in thousands) Six months ended June 30, 2018 2017 Basic: Weighted average number of common shares outstanding 100,628 100,581 Dilutive: Dilutive impact of share options 100 — Weighted average number of common shares outstanding 100,728 100,581 Earnings (loss) per share are as follows: Six months ended June 30, 2018 2017 Basic $ 0.15 $ (1.39 ) Diluted $ 0.15 $ (1.39 )

Other Financial Items (Tables)

Other Financial Items (Tables)	6 Months Ended
	Jun. 30, 2018
Other Income and Expenses [Abstract]
Schedule of Other Financial Items	Other financial items, net comprise of the following: (in thousands of $) Six months ended June 30, 2018 2017 Mark-to-market adjustment for interest rate swap derivatives 7,713 (603 ) Unrealized mark-to-market losses on Earn-Out Units (4,500 ) (500 ) Mark-to-market adjustment for equity derivatives (4,374 ) (4,323 ) Interest income/(expense) on undesignated interest rate swaps 2,596 (2,706 ) Foreign exchange loss on operations (618 ) (944 ) Amortization of debt guarantee 361 846 Financing arrangement fees and other costs (53 ) (239 ) Others (531 ) 541 594 (7,928 )

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Sale Leaseback Transactions	A summary of this sale and lease back arrangement, including repurchase options and obligations as of June 30, 2018 is provided below: Vessel Effective from Sales value (in $ millions) First repurchase option (in $ millions) Date of first repurchase option Repurchase obligation at end of lease term (in $ millions) End of lease term Hilli June 2018 1,200.0 633.2 June 2023 300.0 June 2028
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, 2018 , are shown below: (in thousands of $) 2018 (1) 2019 2020 2021 2022 2023+ Golar Glacier 8,620 17,100 17,147 17,100 17,100 29,984 Golar Kelvin 8,620 17,100 17,147 17,100 17,100 32,795 Golar Snow 8,620 17,100 17,147 17,100 17,100 32,795 Golar Ice 8,620 17,100 17,147 17,100 17,100 35,700 Golar Tundra (2)(3) 11,445 21,910 20,833 19,739 18,695 47,532 Golar Seal (3) 7,513 15,193 15,151 15,151 15,151 45,495 Golar Crystal (2) 6,083 11,934 11,726 11,477 11,271 45,529 Hilli (2) 64,568 126,118 121,036 116,143 111,279 505,666 (1) For the six months ending December 31, 2018. (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. (3) The payment obligations relating to the Golar Tundra and Golar Seal above have been prepared on the assumption that we are able to secure a replacement charter for these two vessels, to ensure continuation of these financing arrangements. Refer to note 1 for further details.
Schedule of Assets and Liabilities of Lessor VIEs	The assets and liabilities of these lessor VIEs that most significantly impact our consolidated balance sheet as of June 30, 2018 and December 31, 2017 , are as follows: (in thousands of $) Golar Glacier Golar Kelvin Golar Snow Golar Ice Golar Tundra Golar Seal Golar Crystal Hilli June 30, 2018 December 31, 2017 Assets Total Total Restricted cash and short-term deposits 18,844 62,319 18,548 8 25,000 22,141 2,372 36,441 185,673 130,063 Liabilities Debt: Current portion of long-term debt and short-term debt (1) 39,314 182,540 30,398 126,508 155,318 143,849 10,075 148,880 836,882 833,664 Long-term interest bearing debt - non-current portion (1) 117,841 — 127,189 — — — 89,246 779,400 1,113,676 252,691 157,155 182,540 157,587 126,508 155,318 143,849 99,321 928,280 1,950,558 1,086,355 (1) Where applicable, these balances are net of deferred finance charges.

Restricted cash and short ter33

Restricted cash and short term deposits (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2018 December 31, 2017 Restricted cash relating to the total return equity swap 62,547 58,351 Restricted cash in relation to the Hilli (1) 175,206 174,737 Restricted cash and short-term deposits held by lessor VIEs 185,673 130,063 Restricted cash relating to the $1.125 billion debt facility 27,384 33,752 Restricted cash relating to office lease 823 813 Bank guarantee 685 99 Total restricted cash and short-term deposits 452,318 397,815 Less: Amounts included in current restricted cash and short-term deposits (276,289 ) (222,265 ) Long-term restricted cash 176,029 175,550 (1) In November 2015, in connection with the issuance of a letter of credit by a financial institution to our project partner involved in the Hilli FLNG project, we were required to provide cash collateral to support the performance guarantee.
Schedule of Cash Flow, Supplemental Disclosures	The following table identifies the balance sheet line-items included in cash, cash equivalents and restricted cash presented in the consolidated statements of cash flows: (in thousands of $) June 30, 2018 December 31, 2017 June 30, 2017 December 31, 2016 Cash and cash equivalents 375,067 214,862 343,226 224,190 Restricted cash and short-term deposits (current portion) 276,289 222,265 205,227 183,693 Restricted cash (non-current portion) 176,029 175,550 233,144 232,335 827,385 612,677 781,597 640,218

Asset Under Development (Tables

Asset Under Development (Tables)	6 Months Ended
	Jun. 30, 2018
Extractive Industries [Abstract]
Schedule for Assets Under Development	(in thousands of $) December 31, 2017 Purchase price installments 962,709 Interest costs capitalized 116,416 Other costs capitalized 98,364 1,177,489

Equity in Net (Losses) Earnings

Equity in Net (Losses) Earnings of Affiliates (Tables)	6 Months Ended
	Jun. 30, 2018
Investments, Debt and Equity Securities [Abstract]
Schedule of Equity Method Investments	Six Months Ended June 30, (in thousands of $) 2018 2017 Share of net earnings (losses) in Golar Partners (1) 8,630 (2,906 ) Share of net loss in Golar Power (12,861 ) (7,461 ) Share of net loss in OneLNG (2,047 ) (3,126 ) Share of net earnings in Egyptian Company for Gas Services ("ECGS") 63 300 (6,215 ) (13,193 ) (1) For the six months ended June 30, 2017 , our share of net earnings (losses) in Golar Partners includes a non-cash loss on deemed disposal of $17.0 million , being the dilutive impact on our ownership interest due to further issuances of common units by Golar Partners in February 2017. The carrying amounts of our investments in our equity method investments as at June 30, 2018 and December 31, 2017 are as follows: (in thousands of $) June 30, 2018 December 31, 2017 Golar Partners 444,525 467,097 Golar Power 258,690 228,696 OneLNG (1) — 2,047 ECGS 5,449 5,385 Equity in net assets of affiliates 708,664 703,225 (1) The delays in finalizing a debt financing package for the Fortuna FLNG project, together with other capital and resource priorities, has resulted in a decision from Schlumberger to end their participation in the project. Golar and Schlumberger, as a result of this, plan to wind down OneLNG and work on FLNG projects as required on a case-by-case basis. As a result, we have written down our investment in OneLNG to $ nil at June 30, 2018 .

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2018 December 31, 2017 FLNG derivative (1) 203,000 94,700 Other non-current assets (2) 24,793 37,891 Mark-to-market interest rate swaps valuation 16,336 10,166 Investment in OLT Offshore LNG Toscana S.p.A (3) 7,347 7,347 Derivatives - other (4) — 7,400 251,476 157,504 (1) "FLNG derivative" refers to a derivative embedded in the Hilli LTA. See note 1 for further details. (2) "Other non-current assets" is mainly comprised of payments made relating to long lead items ordered in preparation for the conversion of the Gimi and the Gandria into FLNG vessels. As of June 30, 2018 and December 31, 2017 , the aggregate carrying value was $15.0 million and $31.0 million , respectively. The Gimi and the Gandria conversion contracts provide the flexibility wherein certain beneficial cancellation provisions exist which, if exercised prior to contract expiry, will allow termination of contracts and recovery of previous milestone payments, less cancellation fees. The Gimi contract will expire on December 30, 2018 and the Gandria contract will expire on December 31, 2018. (3) "Investment in OLT Offshore LNG Toscana S.p.A" ("OLT-O") refers to our investment in an Italian incorporated unlisted company which is involved in the construction, development, operation and maintenance of a FSRU terminal to be situated off the Livorno coast of Italy. In prior years, this investment was classified as a cost method investment. Following the adoption of ASU 2016-01, we have applied the measurement alternative for measuring equity investments without readily determinable fair values. As of June 30, 2018 and December 31, 2017 , our investment in OLT-O was $7.3 million , representing a 2.7% interest in OLT-O’s issued share capital. (4) "Derivatives - other" refers to the Earn-Out Units issuable to us in connection with the IDR Reset transaction with Golar Partners in October 2016.

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Components of Debt	As of June 30, 2018 and December 31, 2017 , our debt was as follows: (in thousands of $) June 30, 2018 December 31, 2017 Golar Arctic facility 61,950 65,600 Golar Viking facility 49,479 52,083 2017 convertible bonds 346,698 340,173 Margin loan (1) 98,252 119,125 FLNG Hilli facility (2) — 525,000 Hilli shareholder loans 49,066 49,066 $1.125 billion facility 184,590 195,449 ICBCL VIE loans (3) 625,665 641,936 CCBFL VIE loan (3) 143,849 143,849 CMBL VIE loan (3) 155,317 198,613 COSCO Shipping VIE loan (3)(4) 100,022 104,006 CSSC VIE loan (2)(3) 928,280 — Total debt 2,743,168 2,434,900 Less: Deferred finance charges, net (18,483 ) (24,053 ) Total debt, net of deferred financing costs 2,724,685 2,410,847 (1) During July 2018, amendments to the existing margin loan facility, secured by units in Golar Partners, were completed. Although most of the existing terms remain substantially unchanged, the facility will no longer amortize. Subject to the satisfaction of certain covenants, no further principal repayments will be required ahead of maturity in March 2020. (2) In June 2018, we repaid $640.0 million on the pre-delivery credit facility and drew down $960.0 million on the post-acceptance sale and leaseback financing in relation to the FLNG Hilli facility. The sale and leaseback arrangement is provided by a related party of CSSC. (3) See note 8. (4) In April 2018, the SPV, Oriental Fleet LNG 01 Limited, which owns the Golar Crystal , entered into a long-term loan facility for $101.0 million . The loan facility is provided by a related party of COSCO Shipping. The loan facility is denominated in USD, is a 10 year loan, limited to the term of the bareboat charter, bears interest at LIBOR plus a margin and is repayable in monthly installments with a balloon payment on maturity. At June 30, 2018 , our debt can be broken down as follows: Golar debt VIE debt (1) Total debt (in thousands of $) Current portion of long-term debt and short-term debt 31,843 836,882 868,725 Long-term debt 742,284 1,113,676 1,855,960 Total 774,127 1,950,558 2,724,685 (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 8).

Accumulated Other Comprehensi38

Accumulated Other Comprehensive (Loss) Income (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2016 (12,956 ) 3,414 (9,542 ) Other comprehensive income — 1,632 1,632 Balance at June 30, 2017 (12,956 ) 5,046 (7,910 ) 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 )

Financial Instruments (Tables)

Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2018
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, 2018 and December 31, 2017 are as follows: June 30, 2018 December 31, 2017 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents Level 1 375,067 375,067 214,862 214,862 Restricted cash and short-term deposits Level 1 452,318 452,318 397,815 397,815 Current portion of long-term debt and short-term debt (1)(2) Level 2 871,507 871,507 1,393,229 1,393,229 Long-term debt - convertible bonds (2) Level 2 346,698 437,063 340,173 430,361 Long-term debt (2) Level 2 1,524,963 1,524,963 701,498 701,498 Derivatives: FLNG derivative (3)(7) Level 2 203,000 203,000 94,700 94,700 Interest rate swaps asset (3)(4) Level 2 17,879 17,879 10,166 10,166 Foreign exchange swaps asset (3) Level 2 35 35 51 51 Foreign exchange swaps liability (3) Level 2 573 573 223 223 Total return equity swap liability (3)(4)(5) Level 2 44,516 44,516 40,141 40,141 Earn-Out Units asset (6) Level 2 2,900 2,900 7,400 7,400 (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 $ 18.5 million and $ 24.1 million at June 30, 2018 and December 31, 2017 , respectively. (3) Derivative liabilities are captured within other current liabilities and derivative assets are generally captured within other 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 Earn-Out Units are issuable to Golar in connection with the IDR Reset transaction between Golar and Golar Partners in October 2016. (7) The fair value of the FLNG derivative 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 FLNG derivative include management’s estimate of an appropriate discount rate and the length of time to blend the long-term and the short-term oil prices obtained from quoted prices in active markets.
Schedule of Designated Cash Flow Hedges	As of June 30, 2018 , 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 1,250,000 2018 to 2021 1.13% to 1.94%
Offsetting Assets	We have elected not to offset the fair values of derivative assets and liabilities executed with the same counterparty that are generally subject to enforceable master netting arrangements. However, if we were to offset and record the asset and liability balances of derivatives on a net basis, the amounts presented in our consolidated balance sheets as of June 30, 2018 and December 31, 2017 would be adjusted as detailed in the following table: June 30, 2018 December 31, 2017 (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 17,879 — 17,879 10,166 — 10,166

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Net revenues: The transactions with OneLNG and its subsidiaries for the six months ended June 30, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue 1,399 2,708 Total 1,399 2,708 Receivables: The balances with OneLNG and its subsidiaries as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Trading balances due from OneLNG (a) 10,912 7,898 Total 10,912 7,898 a) Trading balances - Receivables and payables with One LNG and its subsidiaries are comprised primarily of unpaid management fees, charterhire expenses, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from OneLNG are unsecured, interest-free and intended to be settled in the ordinary course of business. 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 $) 2018 2017 Time and voyage charter revenues 64,605 27,705 Time charter revenues - collaborative arrangement 19,353 11,739 Voyage, charterhire and commission expenses (8,600 ) (82 ) Voyage, charterhire and commission expenses - collaborative arrangement (30,897 ) (12,772 ) Net income from the Cool Pool 44,461 26,590 Receivables from other related parties: (in thousands of $) June 30, 2018 December 31, 2017 Cool Pool (a) 10,514 14,004 10,514 14,004 a) Trade accounts receivable includes amounts due from the Cool Pool arising from our collaborative arrangement, amounting to $10.5 million as of June 30, 2018 (December 31, 2017: $14.0 million ). From our participation in the Cool Pool, we recognized net income of $44.5 million and $26.6 million for the six months ended June 30, 2018 and 2017 , respectively. Net revenues: The transactions with Golar Power and its affiliates for the six months ended June 30, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue 2,457 1,819 Ship management fees income 700 278 Debt guarantee compensation (a) 361 402 Other (247 ) — Total 3,271 2,499 Payables: The balances with Golar Power and its affiliates as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Trading balances due to Golar Power and affiliates (b) (6,803 ) (935 ) Total (6,803 ) (935 ) 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 $0.4 million and $0.4 million income for the six months ended June 30, 2018 and 2017 , 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. Net revenues (expenses): The transactions with Golar Partners and its subsidiaries for the six months ended June 30, 2018 and 2017 consisted of the following: Six Months Ended (in thousands of $) 2018 2017 Management and administrative services revenue (a) 3,877 2,571 Ship management fees revenue (b) 2,600 2,138 Charterhire expense (c) — (9,089 ) Interest expense on deposits payable (d) (4,484 ) (1,404 ) Total 1,993 (5,784 ) Payables: The balances with Golar Partners and its subsidiaries as of June 30, 2018 and December 31, 2017 consisted of the following: (in thousands of $) June 30, 2018 December 31, 2017 Deposit payable (d) (177,247 ) (177,247 ) Methane Princess security lease deposit movement (e) (3,143 ) (3,464 ) Trading balances owing to Golar Partners and affiliates (f) (7,040 ) (4,144 ) Total (187,430 ) (184,855 ) 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) Charterhire expenses - For the six months ended June 30, 2017 , this consists of charterhire expenses that we incurred for the charter back from Golar Partners of the Golar Grand , less any time charter revenues that Golar Partners generated through subleasing the Golar Grand from Golar during the period . On November 1, 2017, the Golar Grand arrangement concluded. d) Interest expense on deposits payable Expense under Tundra Letter Agreement - In May 2016, we completed the Golar Tundra Sale and received a total cash consideration of $107.2 million . We agreed to pay Golar Partners a daily fee plus operating expenses for the right to use the Golar Tundra from the date the Golar Tundra Sale was closed, until the date that the vessel would commence operations under the Golar Tundra Time Charter. In return, Golar Partners agreed to remit to us any hire income received with respect to the Golar Tundra during that period. It was further agreed that, if for any reason the Golar Tundra Time Charter had not commenced by the 12 month anniversary of the closing of the Golar Tundra Sale, Golar Partners had the right to require that we repurchase the shares of Tundra Corp at a price equal to the purchase price. Accordingly, by virtue of the put option, which was exercised by Golar Partners in May 2017, we continued to consolidate the Golar Tundra for the periods whilst the put option remained in place, thus we have accounted for $nil and $1.4 million as interest expense for the six months ended June 30, 2018 and 2017, respectively. Deferred purchase price - In May 2017, the Golar Tundra had not commenced her charter and, accordingly, Golar Partners elected to exercise the Tundra Put Right to require us to repurchase Tundra Corp at a price equal to the original purchase price. In connection with Golar Partners exercising the Tundra Put Right, we and Golar Partners entered into an agreement pursuant to which we agreed to purchase Tundra Corp from Golar Partners on the date of the closing of the Tundra Put Sale (the "Put Sale Closing Date") in return we will be required to pay an amount equal to $107.2 million (the "Deferred Purchase Price") plus an additional amount equal to 5% per annum of the Deferred Purchase Price (the "Additional Amount"). The Deferred Purchase Price and the Additional Amount shall be due and payable by us on the date of the closing of the Hilli Disposal (see below). We agreed to accept the Deferred Purchase Price and the Additional Amount in lieu of a cash receipt on the Put Sale Closing Date in return we have provided Golar Partners with an option (which Golar Partners have exercised) to purchase an interest in Hilli Corp. We have accounted for $2.7 million and nil as interest expense for the six months ended June 30, 2018 and 2017, respectively, in relation to the Deferred Purchase Price. Deposit received from Golar Partners - On August 15, 2017, we entered into a purchase and sale agreement (the "Hilli Sale Agreement") with Golar Partners for the disposal (the "Hilli Disposal") from Golar and affiliates of Keppel and Black & Veatch Corporation of common units (the "Disposal Interests") in Hilli LLC. On the closing date of the Hilli Disposal, Hilli LLC will indirectly (through its subsidiary) be the disponent owner of the Hilli . The Disposal Interests represent the equivalent of 50% of the two liquefaction trains, out of a total of four , that are contracted to Perenco and SNH under an eight -year LTA. The sale price for the Disposal Interests is $658 million less 50% of the net lease obligations under the financing facility for the Hilli (the "Hilli Facility") on closing date, plus post-closing purchase price adjustments. Concurrently with the execution of the Hilli Sale Agreement, we received a further $70 million deposit from Golar Partners, upon which we pay interest at a rate of 5% per annum. We have accounted for $1.8 million and $nil as interest expense for the six months ended June 30, 2018 and 2017, respectively, in relation to the $70 million deposit from Golar Partners. On June 12, 2018, we concluded the Hilli Disposal with Golar Partners, accordingly we applied the Deferred Purchase Price as well as the deposit received from Golar Partners against the disposal. 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. f) 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 in respect of disposals to the Partnership, as well as charterhire expenses. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Trading balances owing to or due from Golar Partners and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. They primarily relate to recharges for trading expenses paid on behalf of Golar Partners, including ship management and administrative service fees due to us. g) Distributions from Golar Partners - During the six months ended June 30, 2018 and June 30, 2017, we received total distributions from Golar Partners of $26.2 million and $25.7 million , respectively in respect of the common units and general partner units owned by us.

Other Commitments and Conting41

Other Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of Assets Pledged	Assets pledged (in thousands of $) June 30, 2018 December 31, 2017 Book value of vessels secured against long-term loans 3,299,901 2,032,747

General (Details)

General (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)$ / barrelcarriernewbuild	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)	Dec. 19, 2017USD ($)
Property, Plant and Equipment [Line Items]
Derivative asset | $	$ 17,879		$ 10,166
Oil Price Per Barrel | $ / barrel	60
Liabilities | $	$ 3,350,279		2,967,983
Golar LNG Partners
Property, Plant and Equipment [Line Items]
Number of carriers operated by other | carrier	10
Golar Power
Property, Plant and Equipment [Line Items]
Number of newbuild commitments contracted for construction | newbuild	1
Sergipe | Golar Power
Property, Plant and Equipment [Line Items]
Ownership percentage	50.00%
Debt instrument, face amount | $	$ 1,340,000
LNG Carrier | Golar Power
Property, Plant and Equipment [Line Items]
Number of carriers operated by other | carrier	2
LNG Carrier | LNG Carrier
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated | carrier	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 | carrier	18
LNG Carrier | Floating Storage Regasification Unit
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated | carrier	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 | carrier	7
LNG Carrier | FLNG
Property, Plant and Equipment [Line Items]
Number of carriers owned and operated | carrier	1
FLNG
Property, Plant and Equipment [Line Items]
Derivative asset | $				$ 79,600
Derivative liability | $			79,600
FLNG derivative | FLNG
Property, Plant and Equipment [Line Items]
Unrealized gain on FLNG derivative instrument | $	$ 108,300	$ 0
FLNG derivative | FLNG | Fair value | Level 2
Property, Plant and Equipment [Line Items]
Derivative asset | $	$ 203,000		$ 94,700

Accounting Policies (Details)

Accounting Policies (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)vessel	Jun. 30, 2017USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses	$ 24,092	$ 18,269
Number of vessels in sale and leaseback transaction | vessel	8
Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses		22,546
Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Administrative expenses		$ (4,277)

Accounting Policies Price risk

Accounting Policies Price risk derivatives (Details) - FLNG derivative - FLNG - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Price Risk Derivatives [Line Items]
Realized gain on FLNG derivative instrument	$ 3,586	$ 0
Unrealized gain on FLNG derivative instrument	108,300	0
Gain on FLNG derivative instrument	$ 111,886	$ 0

Recently Issued Accounting St45

Recently Issued Accounting Standards Recently Issued Accounting Standards (Details) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities			$ 0
Increase (decrease) in restricted cash and cash equivalents, investing activities			0
Increase (decrease) in restricted cash and cash equivalents, financing activities			0
Net increase in cash, cash equivalents and restricted cash	[1]	$ 214,708	141,379
Cash, cash equivalents and restricted cash at beginning of period	[1]	612,677	640,218
Cash, cash equivalents and restricted cash at end of period	[1]	$ 827,385	781,597
Accounting Standards Update 2016-18 [Member] | Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities			(406)
Increase (decrease) in restricted cash and cash equivalents, investing activities			(6,544)
Increase (decrease) in restricted cash and cash equivalents, financing activities			(15,393)
Net increase in cash, cash equivalents and restricted cash			119,036
Cash, cash equivalents and restricted cash at beginning of period			224,190
Cash, cash equivalents and restricted cash at end of period			343,226
Accounting Standards Update 2016-18 [Member] | Restatement Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase (decrease) in restricted cash and cash equivalents, operating activities			406
Increase (decrease) in restricted cash and cash equivalents, investing activities			6,544
Increase (decrease) in restricted cash and cash equivalents, financing activities			15,393
Net increase in cash, cash equivalents and restricted cash			22,343
Cash, cash equivalents and restricted cash at beginning of period			416,028
Cash, cash equivalents and restricted cash at end of period			$ 438,371
[1]	Following the adoption of the amendments to ASC 230, the statement of cash flows presents the change in the period in total cash, cash equivalents and restricted cash. These amendments have been applied retrospectively for the six months ended June 30, 2017.

Segment Information - Narrative

Segment Information - Narrative (Details)	6 Months Ended
	Jun. 30, 2018segment
Segment Reporting [Abstract]
Number of Reportable Segments	3

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Total operating revenues	$ 125,564	$ 53,518
Depreciation and amortization	(36,866)	(42,552)
Other operating expenses	(115,230)	(76,326)
Other operating gains and losses	111,366	0
Operating income (loss) before inter-segment eliminations	84,834	(65,360)
Operating (loss) income	84,834	(65,360)
Equity in net earnings (losses) of affiliates	(6,215)	(13,193)
Total assets	5,192,974		$ 4,764,287
Investments in affiliates	708,664		703,225
Operating Segments | Vessel Operations
Segment Reporting Information [Line Items]
Total operating revenues	106,987	53,518
Depreciation and amortization	(32,775)	(42,552)
Other operating expenses	(103,058)	(76,100)
Other operating gains and losses	10,000	0
Operating income (loss) before inter-segment eliminations	(18,846)	(65,134)
Operating (loss) income	(18,641)	(64,935)
Equity in net earnings (losses) of affiliates	8,693	(2,606)
Total assets	2,882,837		3,025,244
Investments in affiliates	449,974		472,482
Operating Segments | FLNG
Segment Reporting Information [Line Items]
Total operating revenues	18,577	0
Depreciation and amortization	(4,091)	0
Other operating expenses	(12,172)	(226)
Other operating gains and losses	101,366	0
Operating income (loss) before inter-segment eliminations	103,680	(226)
Operating (loss) income	103,680	(226)
Equity in net earnings (losses) of affiliates	(2,047)	(3,126)
Total assets	2,056,768		1,515,463
Investments in affiliates	0		2,047
Operating Segments | Power Segment
Segment Reporting Information [Line Items]
Total operating revenues	0	0
Depreciation and amortization	0	0
Other operating expenses	0	0
Other operating gains and losses	0	0
Operating income (loss) before inter-segment eliminations	0	0
Operating (loss) income	0	0
Equity in net earnings (losses) of affiliates	(12,861)	(7,461)
Total assets	258,690		228,696
Investments in affiliates	258,690		228,696
Intersegment Eliminations
Segment Reporting Information [Line Items]
Total operating revenues	0	0
Depreciation and amortization	0	0
Other operating expenses	0	0
Other operating gains and losses	0	0
Operating income (loss) before inter-segment eliminations	0	0
Operating (loss) income	(205)	(199)
Equity in net earnings (losses) of affiliates	0	0
Total assets	(5,321)		(5,116)
Investments in affiliates	0		$ 0
Intersegment Eliminations | Vessel Operations
Segment Reporting Information [Line Items]
Operating (loss) income	205	199
Intersegment Eliminations | FLNG
Segment Reporting Information [Line Items]
Operating (loss) income	0	0
Intersegment Eliminations | Power Segment
Segment Reporting Information [Line Items]
Operating (loss) income	$ 0	$ 0

Segment information - Revenue f

Segment information - Revenue from external customers (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 125,564	$ 53,518
Sales Revenue, Net | The Cool Pool | Customer Concentration Risk
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 83,959	$ 39,444
Concentration Risk, Percentage	74.00%	90.00%
Sales Revenue, Net | Perenco and SNH | Customer Concentration Risk
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 18,577	$ 0
Concentration Risk, Percentage	16.00%	0.00%
Sales Revenue, Net | An Energy and Logistics Company | Customer Concentration Risk
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 4,579	$ 4,579
Concentration Risk, Percentage	4.00%	10.00%

Revenue Change in Contract Bala

Revenue Change in Contract Balances (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)
Change in Contract with Customer, Asset [Abstract]
Contract with customer, asset, net, beginning balance	$ 17,245
Payments received for services billed	(9,989)
Services provided and billed in current period	31,535
Payments received for services billed in current period	(13,631)
Impairment	(1,006)
Contract with customer, asset, net, ending balance	24,154
Change in Contract with Customer, Liability [Abstract]
Contract with customer, liability, beginning balance	0
Services provided and billed in current period	33,763
Deferred commissioning period billing	(357)
Contract with customer, liability, ending balance	$ 33,406

Revenue Management Fee Revenue

Revenue Management Fee Revenue (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Amounts due from related parties	$ 10,912	$ 7,898
Amounts due to related parties	17,074	8,734
Golar LNG Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Amounts due from related parties	3,100	7,200
Amounts due to related parties	$ 1,000	$ 10,000

Revenue Liquefaction services r

Revenue Liquefaction services revenue (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)$ / barrel	Jun. 30, 2017USD ($)
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	$ 125,564	$ 53,518
Oil Price Per Barrel | $ / barrel	60
Contract with customer, liability, revenue recognized	$ 33,763
Base tolling fee
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	17,427	0
Liquefaction Services
Disaggregation of Revenue [Line Items]
Liquefaction services revenue	18,577	0
Amortization of deferred commissioning period billing	357	0
Amortization of Day 1 gain	841	0
Decrease in Revenue	$ (50)	$ 0

(Losses) Earnings Per Share (De

(Losses) Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income (loss) attributable to Golar LNG Ltd stockholders - basic and diluted	$ 15,317	$ (139,651)
Weighted average number of common shares outstanding, basic (in shares)	100,628	100,581
Weighted average number of common shares outstanding, basic and diluted (in shares)	100,728	100,581
Losses per share
Basic and diluted (in USD per share)	$ 0.15	$ (1.39)
Employee Stock Option
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Dilutive impact of share options (in shares)	100	0

Other Financial Items - Schedul

Other Financial Items - Schedule of Other Financial Items (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Foreign exchange loss on operations	$ (618)	$ (944)
Amortization of debt guarantee	361	846
Financing arrangement fees and other costs	(53)	(239)
Others	(531)	541
Other financial items, net	594	(7,928)
Interest Rate Swaps
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-market adjustment for derivatives	7,713	(603)
Interest Income (Expense), Net	2,596	(2,706)
Earn-out Units
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-market adjustment for derivatives	(4,500)	(500)
Equity Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-market adjustment for derivatives	$ (4,374)	$ (4,323)

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) $ in Thousands	6 Months Ended		12 Months Ended
	Jun. 30, 2018USD ($)vessel	Jun. 30, 2017USD ($)	Dec. 31, 2017vessel
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	8
Interest expense | $	$ 38,012	$ 39,710
Net cash received in financing activities | $	$ (328,799)	(364,072)
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	8		8
Sale and leaseback term	10 years
Interest expense | $	$ 19,100	19,100
Net cash received in financing activities | $	$ 864,700	$ 89,200
Variable Interest Entity, Primary Beneficiary | ICBCL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	4		4
Variable Interest Entity, Primary Beneficiary | CMBL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	1		1
Variable Interest Entity, Primary Beneficiary | CCBFL Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	1		1
Variable Interest Entity, Primary Beneficiary | COSCO Shipping Agreement
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	1		1
Variable Interest Entity, Primary Beneficiary | CSSC
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction	1		1

Variable Interest Entities - Sa

Variable Interest Entities - Sale and Leaseback summary (Details) - Hilli - Variable Interest Entity, Primary Beneficiary - CSSC - Hilli / CSSC $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Variable Interest Entity [Line Items]
Sales value	$ 1,200
First repurchase option	633.2
Last repurchase option	$ 300

Variable Interest Entities - Su

Variable Interest Entities - Summary of Bareboat Charters (Details) - Variable Interest Entity, Primary Beneficiary $ in Thousands	Jun. 30, 2018USD ($)
ICBCL Agreement | Golar Glacier
Variable Interest Entity [Line Items]
2,018	$ 8,620
2,019	17,100
2,020	17,147
2,021	17,100
2,022	17,100
After 2,023	29,984
ICBCL Agreement | Golar Kelvin
Variable Interest Entity [Line Items]
2,018	8,620
2,019	17,100
2,020	17,147
2,021	17,100
2,022	17,100
After 2,023	32,795
ICBCL Agreement | Golar Snow
Variable Interest Entity [Line Items]
2,018	8,620
2,019	17,100
2,020	17,147
2,021	17,100
2,022	17,100
After 2,023	32,795
ICBCL Agreement | Golar Ice
Variable Interest Entity [Line Items]
2,018	8,620
2,019	17,100
2,020	17,147
2,021	17,100
2,022	17,100
After 2,023	35,700
CMBL Agreement | Golar Tundra
Variable Interest Entity [Line Items]
2,018	11,445
2,019	21,910
2,020	20,833
2,021	19,739
2,022	18,695
After 2,023	47,532
CCBFL Agreement | Golar Seal
Variable Interest Entity [Line Items]
2,018	7,513
2,019	15,193
2,020	15,151
2,021	15,151
2,022	15,151
After 2,023	45,495
COSCO Shipping Agreement | Golar Crystal
Variable Interest Entity [Line Items]
2,018	6,083
2,019	11,934
2,020	11,726
2,021	11,477
2,022	11,271
After 2,023	45,529
CSSC | Hilli
Variable Interest Entity [Line Items]
2,018	64,568
2,019	126,118
2,020	121,036
2,021	116,143
2,022	111,279
After 2,023	$ 505,666

Variable Interest Entities - Sc

Variable Interest Entities - Schedule of Assets and Liabilities of Lessor VIEs (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Debt:
Current portion of long-term debt and short-term debt	$ 868,725
Long-term debt	1,855,960	$ 1,025,914
Total liabilities	3,350,279	2,967,983
Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	185,673	130,063
Debt:
Short-term interest bearing debt		833,664
Current portion of long-term debt and short-term debt	836,882
Long-term debt	1,113,676	252,691
Total liabilities	1,950,558	$ 1,086,355
ICBCL Agreement | Golar Glacier | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	18,844
Debt:
Short-term interest bearing debt	39,314
Long-term debt	117,841
Total liabilities	157,155
ICBCL Agreement | Golar Kelvin | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	62,319
Debt:
Short-term interest bearing debt	182,540
Long-term debt	0
Total liabilities	182,540
ICBCL Agreement | Golar Snow | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	18,548
Debt:
Short-term interest bearing debt	30,398
Long-term debt	127,189
Total liabilities	157,587
ICBCL Agreement | Golar Ice | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	8
Debt:
Short-term interest bearing debt	126,508
Long-term debt	0
Total liabilities	126,508
CMBL Agreement | Golar Tundra | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	25,000
Debt:
Short-term interest bearing debt	155,318
Long-term debt	0
Total liabilities	155,318
CCBFL Agreement | Golar Seal | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	22,141
Debt:
Short-term interest bearing debt	143,849
Long-term debt	0
Total liabilities	143,849
COSCO Shipping Agreement | Golar Crystal | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	2,372
Debt:
Short-term interest bearing debt	10,075
Long-term debt	89,246
Total liabilities	99,321
CSSC | Hilli | Variable Interest Entity, Primary Beneficiary
Assets
Restricted cash and short-term deposits	36,441
Debt:
Short-term interest bearing debt	148,880
Long-term debt	779,400
Total liabilities	$ 928,280

Restricted cash and short ter58

Restricted cash and short term deposits Restricted cash and short-term deposits, composition (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 452,318,000	$ 397,815,000
Restricted cash and cash equivalents, current	(276,289,000)	(222,265,000)	$ (205,227,000)	$ (183,693,000)
Restricted cash	176,029,000	175,550,000	$ 233,144,000	$ 232,335,000
Return Equity Swap
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	62,547,000	58,351,000
Letter of Credit
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	175,206,000	174,737,000
Lessor VIEs
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	185,673,000	130,063,000
Office lease
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	823,000	813,000
Bank guarantee
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	685,000	99,000
$1.125 billion facility | Interest-bearing Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	27,384,000	33,752,000
Secured Debt | Line of Credit | $1.125 billion facility
Restricted Cash and Cash Equivalents Items [Line Items]
Maximum borrowing capacity	$ 1,125,000,000	$ 1,125,000,000

Restricted cash and short ter59

Restricted cash and short term deposits Cash and restricted cash, summary (Details) - USD ($) $ in Thousands		Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents		$ 375,067	$ 214,862	$ 343,226	$ 224,190
Restricted cash and short-term deposits		276,289	222,265	205,227	183,693
Restricted cash		176,029	175,550	233,144	232,335
Cash, cash equivalents, restricted cash and restricted cash equivalents	[1]	$ 827,385	$ 612,677	$ 781,597	$ 640,218
[1]	Following the adoption of the amendments to ASC 230, the statement of cash flows presents the change in the period in total cash, cash equivalents and restricted cash. These amendments have been applied retrospectively for the six months ended June 30, 2017.

Asset Under Development (Detail

Asset Under Development (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Asset under development	$ 0	$ 1,177,489
Hilli Conversion to FLNG
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Purchase price installments		962,709
Interest costs capitalized		116,416
Other costs capitalized		98,364
Asset under development		$ 1,177,489

Equity in Net (Losses) Earnin61

Equity in Net (Losses) Earnings of Affiliates (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Debt Securities, Available-for-sale [Line Items]
Equity in net earnings (losses) of affiliates	$ (6,215)	$ (13,193)
Golar Partners
Debt Securities, Available-for-sale [Line Items]
Equity in net earnings (losses) of affiliates	8,630	(2,906)
Non cash loss on deemed disposal	17,000
Golar Power
Debt Securities, Available-for-sale [Line Items]
Equity in net earnings (losses) of affiliates	(12,861)	(7,461)
OneLNG
Debt Securities, Available-for-sale [Line Items]
Equity in net earnings (losses) of affiliates	(2,047)	(3,126)
Egyptian Company for Gas Services (ECGS)
Debt Securities, Available-for-sale [Line Items]
Equity in net earnings (losses) of affiliates	$ 63	$ 300

Equity in Net (Losses) Earnin62

Equity in Net (Losses) Earnings of Affiliates - Schedule of Carrying Amount of Equity Method Investments (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	$ 708,664	$ 703,225
Golar Partners
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	444,525	467,097
Golar Power
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	258,690	228,696
OneLNG
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	0	2,047
ECGS
Schedule of Equity Method Investments [Line Items]
Equity in net assets of affiliates	$ 5,449	$ 5,385

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Components of Other Non-Current Assets:
Other non-current assets	$ 24,793	$ 37,891
Total other non-current assets	251,476	157,504
OLT Offshore LNG Toscana
Components of Other Non-Current Assets:
Investment in OLT Offshore LNG Toscana	$ 7,347	$ 7,347
Ownership percentage	2.70%	2.70%
Golar Gimi and Gandria
Components of Other Non-Current Assets:
Other non-current assets	$ 15,000	$ 31,000
Interest Rate Swaps
Components of Other Non-Current Assets:
Derivatives	16,336	10,166
Earn-out Units
Components of Other Non-Current Assets:
Derivatives	0	7,400
FLNG | FLNG derivative
Components of Other Non-Current Assets:
Derivatives	$ 203,000	$ 94,700

Debt - Components of Debt (Deta

Debt - Components of Debt (Details) - USD ($)	1 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018	Jun. 30, 2017	Apr. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total debt	$ 2,743,168,000	$ 2,743,168,000			$ 2,434,900,000
Less: Deferred finance charges, net	(18,483,000)	(18,483,000)			(24,053,000)
Total debt, net of deferred financing costs	2,724,685,000	2,724,685,000			2,410,847,000
Repayments of Debt		874,256,000	$ 371,268,000
Secured Debt | Golar Arctic facility
Debt Instrument [Line Items]
Total debt	61,950,000	61,950,000			65,600,000
Secured Debt | Golar Viking facility
Debt Instrument [Line Items]
Total debt	49,479,000	49,479,000			52,083,000
Secured Debt | Margin Loan Facility
Debt Instrument [Line Items]
Total debt	98,252,000	98,252,000			119,125,000
Secured Debt | FLNG Hilli facility (2)
Debt Instrument [Line Items]
Total debt	0	0			525,000,000
Secured Debt | $1.125 billion facility
Debt Instrument [Line Items]
Total debt	184,590,000	184,590,000			195,449,000
Secured Debt | ICBC VIE loans
Debt Instrument [Line Items]
Total debt	625,665,000	625,665,000			641,936,000
Secured Debt | Seal VIE loan
Debt Instrument [Line Items]
Total debt	143,849,000	143,849,000			143,849,000
Secured Debt | Tundra VIE loan
Debt Instrument [Line Items]
Total debt	155,317,000	155,317,000			198,613,000
Secured Debt | Crystal VIE loan
Debt Instrument [Line Items]
Total debt	100,022,000	100,022,000			104,006,000
Debt instrument, face amount				$ 101,000,000
Secured Debt | CSSC VIE Loan [Member]
Debt Instrument [Line Items]
Total debt	928,280,000	928,280,000			0
Convertible Debt | 2017 convertible bonds
Debt Instrument [Line Items]
Total debt	346,698,000	346,698,000			340,173,000
Shareholder Notes Payable | Hilli shareholder loans
Debt Instrument [Line Items]
Total debt	49,066,000	49,066,000			49,066,000
Hilli / CSSC | Affiliated Entity [Member] | FLNG Hilli facility (2)
Debt Instrument [Line Items]
Repayments of Debt	640,000,000
Hilli / CSSC | Variable Interest Entity, Primary Beneficiary | Affiliated Entity [Member] | FLNG Hilli facility (2)
Debt Instrument [Line Items]
Debt instrument, face amount	960,000,000	960,000,000
Line of Credit | Secured Debt | $1.125 billion facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 1,125,000,000	$ 1,125,000,000			$ 1,125,000,000

Debt Debt - Summary (Details)

Debt Debt - Summary (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	$ 868,725
Long-term debt	1,855,960	$ 1,025,914
Total	2,724,685
Variable Interest Entity, Primary Beneficiary
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	836,882
Long-term debt	1,113,676	$ 252,691
Total	1,950,558
Golar
Debt Instrument [Line Items]
Current portion of long-term debt and short-term debt	31,843
Long-term debt	742,284
Total	$ 774,127

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Debt Instrument [Line Items]
Repayments of Debt		$ 874,256	$ 371,268
Total debt	$ 2,743,168	2,743,168		$ 2,434,900
Secured Debt | FLNG Hilli facility (2)
Debt Instrument [Line Items]
Total debt	0	0		$ 525,000
Secured Debt | Hilli Lessor VIE
Debt Instrument [Line Items]
Total debt	840,000	840,000
Affiliated Entity [Member] | Secured Debt | Hilli Lessor VIE
Debt Instrument [Line Items]
Total debt	120,000	$ 120,000
Affiliated Entity [Member] | Hilli / CSSC | FLNG Hilli facility (2)
Debt Instrument [Line Items]
Repayments of Debt	$ 640,000

Accumulated Other Comprehensi67

Accumulated Other Comprehensive (Loss) Income (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 1,796,304	$ 1,909,826
Other comprehensive income	(24,137)	1,632
Ending balance	1,842,695	1,822,646
Pension and post-retirement benefit plan adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(12,799)	(12,956)
Other comprehensive income	0	0
Ending balance	(12,799)	(12,956)
Share of affiliates' comprehensive income
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	5,030	3,414
Other comprehensive income	(24,137)	1,632
Ending balance	(19,107)	5,046
Total accumulated comprehensive loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(7,769)	(9,542)
Other comprehensive income	(24,137)	1,632
Ending balance	$ (31,906)	$ (7,910)

Financial Instruments (Details)

Financial Instruments (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017	Dec. 19, 2017	Jun. 30, 2017	Dec. 31, 2016
Non-Derivatives:
Cash and cash equivalents	$ 375,067,000	$ 214,862,000		$ 343,226,000	$ 224,190,000
Restricted cash and cash equivalents	452,318,000	397,815,000
Debt, current		1,384,933,000
Long-term debt	1,855,960,000	1,025,914,000
Derivatives:
Derivative asset	17,879,000	10,166,000
Deferred finance charges	18,483,000	24,053,000
Interest Rate Swaps | Cash Flow Hedging
Derivatives:
Notional value	$ 1,250,000,000
Interest Rate Swaps | Minimum | Cash Flow Hedging
Derivatives:
Fixed interest rates	1.13%
Interest Rate Swaps | Maximum | Cash Flow Hedging
Derivatives:
Fixed interest rates	1.94%
Carrying value | Level 1
Non-Derivatives:
Cash and cash equivalents	$ 375,067,000	214,862,000
Restricted cash and cash equivalents	452,318,000	397,815,000
Carrying value | Level 2
Non-Derivatives:
Debt, current	871,507,000	1,393,229,000
Long-term debt - convertible bonds	346,698,000	340,173,000
Long-term debt	1,524,963,000	701,498,000
Carrying value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	17,879,000	10,166,000
Carrying value | Level 2 | Foreign Exchange Swaps
Derivatives:
Foreign exchange swaps asset	35,000	51,000
Foreign exchange swaps liability	573,000	223,000
Carrying value | Level 2 | Return Equity Swap
Derivatives:
Derivative liability	44,516,000	40,141,000
Carrying value | Level 2 | Earn-out Units
Derivatives:
Derivative asset	2,900,000	7,400,000
Fair value | Level 1
Non-Derivatives:
Cash and cash equivalents, fair value disclosure	375,067,000	214,862,000
Restricted cash and cash equivalents, fair value disclosure	452,318,000	397,815,000
Fair value | Level 2
Non-Derivatives:
Debt, current, fair value disclosure	871,507,000	1,393,229,000
Convertible debt, fair value disclosures	437,063,000	430,361,000
Long-term debt, fair value	1,524,963,000	701,498,000
Fair value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	17,879,000	10,166,000
Fair value | Level 2 | Foreign Exchange Swaps
Derivatives:
Foreign exchange swaps asset	35,000	51,000
Foreign exchange swaps liability	573,000	223,000
Fair value | Level 2 | Return Equity Swap
Derivatives:
Derivative liability	44,516,000	40,141,000
Fair value | Level 2 | Earn-out Units
Derivatives:
Derivative asset	2,900,000	7,400,000
FLNG
Derivatives:
Derivative asset			$ 79,600,000
Derivative liability		79,600,000
FLNG | Carrying value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	203,000,000	94,700,000
FLNG | Fair value | Level 2 | Interest Rate Swaps
Derivatives:
Derivative asset	$ 203,000,000	$ 94,700,000

Financial Instruments - Offsett

Financial Instruments - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	$ 17,879	$ 10,166
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	0	0
Net amount	17,879	$ 10,166
Cash Collateral for Borrowed Securities	$ 62,500

Related Party Transactions - Tr

Related Party Transactions - Transactions and balances with Golar Partners and Subsidiaries (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	May 31, 2017	May 31, 2016
Related Party Transaction [Line Items]
Total operating revenues	$ 125,564	$ 53,518
Due from (to) related party	10,514		$ 14,004
Golar LNG Partners
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	1,993	(5,784)
Due from (to) related party	(187,430)		(184,855)
Golar LNG Partners | Management and administrative services revenue
Related Party Transaction [Line Items]
Total operating revenues	3,877	2,571
Golar LNG Partners | Ship management fees revenue
Related Party Transaction [Line Items]
Total operating revenues	2,600	2,138
Golar LNG Partners | Charterhire expense
Related Party Transaction [Line Items]
Related party expense	0	(9,089)
Golar LNG Partners | Interest expense on deposits payable
Related Party Transaction [Line Items]
Related party interest expense	(4,484)	(1,404)
Golar LNG Partners | Methane Princess security lease deposit movement [Member]
Related Party Transaction [Line Items]
Due from (to) related party	(3,143)		(3,464)
Golar LNG Partners | Deposits Due to Affiliates
Related Party Transaction [Line Items]
Related party interest expense	(2,700)	$ 0
Due from (to) related party	(177,247)		(177,247)	$ (107,200)	$ (107,200)
Golar LNG Partners | Trading Balances Due from Affiliates [Member]
Related Party Transaction [Line Items]
Due from (to) related party	$ (7,040)		$ (4,144)

Related Party Transactions - Go

Related Party Transactions - Golar Partners and Subsidiaries Footnotes (Details) $ in Thousands	Aug. 15, 2017USD ($)train	May 31, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)	May 31, 2016USD ($)
Related Party Transaction [Line Items]
Due from (to) related party			$ 10,514		$ 14,004
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			$ (187,430)		(184,855)
Additional amount, percent per annum of Deferred Purchase Price		5.00%
Distributions from related party			26,200	$ 25,700
Golar LNG Partners | Golar Hilli LLC | 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
Sale price for disposal interests	$ 658,000
Golar LNG Partners | Deposits Due to Affiliates
Related Party Transaction [Line Items]
Due from (to) related party		$ (107,200)	(177,247)		$ (177,247)	$ (107,200)
Interest expense, related party			2,700	0
Golar LNG Partners | Tundra Letter Agreement, Interest expense on deposits payable
Related Party Transaction [Line Items]
Interest expense, related party			0	1,400
Golar LNG Partners | Deposit Received
Related Party Transaction [Line Items]
Related party transaction rate	5.00%
Interest expense, related party			$ 1,800	$ 0
Related party transaction amount	$ 70,000
Golar LNG Partners | Golar Management
Related Party Transaction [Line Items]
Termination of related party agreement, period of written notice			30 days

Related Party Transactions - 72

Related Party Transactions - Transactions and balances with Golar Power and Affiliates (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Total operating revenues	$ 125,564	$ 53,518
Due from (to) related party	10,514		$ 14,004
Golar Power
Related Party Transaction [Line Items]
Related Party Transaction, Net Income (Expense) from Related Parties	3,271	2,499
Due from (to) related party	(6,803)		(935)
Golar Power | Management and administrative services revenue
Related Party Transaction [Line Items]
Total operating revenues	2,457	1,819
Golar Power | Ship management fees revenue
Related Party Transaction [Line Items]
Total operating revenues	700	278
Golar Power | Debt Guarantee Compensation
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	361	402
Golar Power | Share Options Expense Recharge
Related Party Transaction [Line Items]
Related party revenues	(247)	$ 0
Golar Power | Trading balances due to Golar Power and affiliates
Related Party Transaction [Line Items]
Due from (to) related party	$ (6,803)		$ (935)

Related Party Transactions - 73

Related Party Transactions - Transactions and balances with OneLNG and Subsidiaries (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Due from (to) related party	$ 10,514		$ 14,004
OneLNG
Related Party Transaction [Line Items]
Due from (to) related party	10,912		7,898
OneLNG | Management and administrative services revenue
Related Party Transaction [Line Items]
Related party revenues	1,399	$ 2,708
OneLNG | Trading Balances Due from OneLNG
Related Party Transaction [Line Items]
Impairment of related party transaction	10,000
Due from (to) related party	$ 10,912		$ 7,898

Related Party Transactions - Ea

Related Party Transactions - Earnings Generated from Participation in The Cool Pool (Details) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Total operating revenues		$ 125,564	$ 53,518
Voyage and charterhire expenses		(10,107)	(15,965)
Due from (to) related party		10,514		$ 14,004
Accounts receivable, gross, current	[1]	27,860		14,980
The Cool Pool
Related Party Transaction [Line Items]
Net income (expenses) from related party transactions		44,461	26,590
Due from (to) related party		10,514		14,004
Accounts receivable, gross, current		10,500		$ 14,000
Non-collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Voyage and charterhire expenses		(8,600)	(82)
Collaborative Arrangement
Related Party Transaction [Line Items]
Voyage and charterhire expenses		(30,897)	(12,772)
Collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Voyage and charterhire expenses		(30,897)	(12,772)
Time and Voyage Charter
Related Party Transaction [Line Items]
Total operating revenues		76,433	32,284
Time and Voyage Charter | Non-collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Total operating revenues		64,605	27,705
Time Charter
Related Party Transaction [Line Items]
Total operating revenues		19,353	11,739
Time Charter | Collaborative Arrangement | The Cool Pool
Related Party Transaction [Line Items]
Total operating revenues		$ 19,353	$ 11,739
[1]	This includes amounts arising from transactions with related parties (see note 16).

Other Commitments and Conting75

Other Commitments and Contingencies Other Commitments and Contingencies - Pledged Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Book value of vessels secured against long-term loans	$ 3,299,901	$ 2,032,747

Other Commitments and Conting76

Other Commitments and Contingencies - Narrative (Details) £ in Millions, $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2018GBP (£)tax_lease	Dec. 31, 2003GBP (£)tax_lease	Jun. 30, 2018USD ($)shares
Loss Contingencies [Line Items]
Number of tax leases | tax_lease		6
Gross cash benefit received from tax leases | £		£ 41
Number of tax leases terminated | tax_lease	5
Number of tax leases remaining | tax_lease	1
Minimum
Loss Contingencies [Line Items]
Estimate of possible exposure | £	£ 0
Maximum
Loss Contingencies [Line Items]
Estimate of possible exposure | £	£ 112
Margin Loan Facility | Golar Partners, Common Units
Loss Contingencies [Line Items]
Number of common units pledged as security (in shares) | shares			21,226,586
ECGS
Loss Contingencies [Line Items]
Commitments and Contingencies | $			$ 1
Shareholders' Agreement, Project to Fund Development of Pipeline Infrastructure and FSRU [Member]
Loss Contingencies [Line Items]
Contractual Obligation | $			0.5
Shareholders' Agreement, Project to Fund Development of Pipeline Infrastructure and FSRU [Member] | Maximum
Loss Contingencies [Line Items]
Contractual Obligation | $			$ 15

Subsequent Events (Details)

Subsequent Events (Details) - Subsequent Event - $ / shares	Jul. 12, 2018	Jul. 31, 2018	Aug. 23, 2018
Subsequent Event [Line Items]
Dividend declared (in USD per share)			$ 0.125
Decrease in ownership	50.00%
Guarantee of portion of indebtedness		50.00%