Golar LNG Limited (GLNG) 20-F31 Mar 232022 FY Annual report (foreign)Financial data

Company Profile

Cover Page

Cover Page	12 Months Ended
Cover Page	Dec. 31, 2022 shares
Entity Information [Line Items]
Document Type	20-F
Document Registration Statement	false
Document Annual Report	true
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Document Shell Company Report	false
Entity File Number	000-50113
Entity Registrant Name	Golar LNG Limited
Entity Incorporation, State or Country Code	D0
Entity Address, City or Town	Hamilton
Entity Address, Postal Zip Code	HM 11
Entity Address, Country	BM
Entity Address, Address Line One	2nd Floor, S.E. Pearman Building
Entity Address, Address Line Two	9 Par-la-Ville Road
Title of 12(b) Security	Common Shares, par value, $1.00 per share
Trading Symbol	GLNG
Security Exchange Name	NASDAQ
Entity Common Stock, Shares Outstanding	107,225,832
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Accounting Standard	U.S. GAAP
Entity Shell Company	false
Entity Central Index Key	0001207179
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Amendment Flag	false
Business Contact
Entity Information [Line Items]
Entity Address, City or Town	Hamilton
Entity Address, Postal Zip Code	HM 11
Entity Address, Country	BM
Entity Address, Address Line One	S.E. Pearman Building
Entity Address, Address Line Two	2nd Floor 9 Par-la-Ville Road
Contact Personnel Name	Mi Hong Yoon
City Area Code	441
Local Phone Number	295-4705

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2022
Auditor Information [Abstract]
Auditor Name	Ernst & Young LLP
Auditor Location	London, United Kingdom
Auditor Firm ID	1438

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Total operating revenues	$ 267,740	$ 260,273	$ 261,388
Vessel operating expenses	(72,802)	(64,366)	(57,252)
Voyage, charterhire and commission expenses	(2,444)	(669)	(1,544)
Administrative expenses	(38,100)	(35,311)	(34,376)
Project development expenses	(8,017)	(2,521)	(8,616)
Depreciation and amortization	(51,712)	(55,362)	(55,940)
Impairment of long-lived assets	(76,155)	0	0
Total operating expenses	(249,230)	(158,229)	(157,728)
Realized and unrealized gain/(loss) on oil and gas derivative instruments	520,997	204,663	(42,561)
Other operating losses	15,417	0	0
Total other operating income/(losses)	505,580	204,663	(42,561)
Operating income	524,090	306,707	61,099
Realized and unrealized mark-to-market gain/(losses) on our investment in listed equity securities	400,966	(295,777)	0
Other non-operating income/(losses), net	11,916	(66,027)	5,682
Total other non-operating income/(losses)	412,882	(361,804)	5,682
Interest income	12,225	128	1,479
Interest expense	(19,286)	(34,486)	(39,182)
Gains/(losses) on derivative instruments, net	71,497	24,348	(52,423)
Other financial items, net	(5,380)	693	(557)
Net financial income/(expense)	59,056	(9,317)	(90,683)
Income/(loss) before taxes and net income/(losses) from equity method investments	996,028	(64,414)	(23,902)
Income taxes	438	(1,440)	(579)
Net income/(losses) from equity method investments	19,041	1,080	(537)
Net income/(loss) from continuing operations	1,015,507	(64,774)	(25,018)
Net (loss)/income from discontinued operations	(76,450)	625,389	(142,912)
Net income/(loss)	939,057	560,615	(167,930)
Total net income attributable to non-controlling interests	(151,284)	(146,764)	(105,627)
Net income/(loss) attributable to stockholders of Golar LNG Limited	$ 787,773	$ 413,851	$ (273,557)
Earnings/(loss) per share attributable to Golar LNG Ltd stockholders Per common share amounts:
Basic earnings/(loss) per share from continuing operations (in dollars per share)	$ 8.09	$ (1.60)	$ (0.96)
Dilutive earnings/(loss) per share from continuing operations (in dollars per share)	8.04	(1.60)	(0.96)
Basic (loss)/earnings per share from discontinued operations (in dollars per share)	(0.79)	5.38	(1.84)
Diluted (loss)/earnings per share from discontinued operations (in dollars per share)	$ (0.79)	$ 5.38	$ (1.84)
Continuing operations
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Depreciation and amortization	$ (51,712)	$ (55,362)	$ (55,940)
Realized and unrealized mark-to-market gain/(losses) on our investment in listed equity securities	400,966	(295,777)	0
Income taxes	(438)	1,440	579
Net income/(losses) from equity method investments	19,041	1,080	(537)
Net income/(loss) from continuing operations	1,015,507	(64,774)	(25,018)
Total net income attributable to non-controlling interests	(143,078)	(111,186)	(68,974)
Discontinued operations
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Depreciation and amortization	(8,732)	(50,590)	(51,983)
Net income/(losses) from equity method investments	0	0	(175,988)
Total net income attributable to non-controlling interests	(8,206)	(35,578)	(36,653)
Liquefaction services revenue
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Total operating revenues	213,970	221,020	226,061
Vessel management fees and other revenues
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Total operating revenues	44,085	27,777	20,695
Time and voyage charter revenues
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
Total operating revenues	$ 9,685	$ 11,476	$ 14,632

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Net income/(loss)		$ 939,057	$ 560,615	$ (167,930)
Other comprehensive income/(loss):
Gain/(loss) associated with pensions, net of tax		5,820	5,006	(3,527)
Share of equity method investment’s comprehensive losses from continuing operations		(800)	0	0
Realized accumulated comprehensive losses on disposal of investment in affiliate		0	43,380	0
Net other comprehensive income/(loss)		5,023	45,239	(21,207)
Comprehensive income/(loss)		944,080	605,854	(189,137)
Comprehensive income/(loss) attributable to:
Stockholders of Golar LNG Limited		792,796	459,090	(294,764)
Comprehensive income/(loss)		944,080	605,854	(189,137)
Continuing operations
Other comprehensive income/(loss):
Share of equity method investment’s comprehensive losses from continuing operations	[1]	(797)	0	0
Comprehensive income/(loss) attributable to:
Non-controlling interests		143,078	111,186	68,974
Discontinued operations
Other comprehensive income/(loss):
Share of equity method investment’s comprehensive losses from continuing operations	[1]	0	(3,147)	(17,680)
Comprehensive income/(loss) attributable to:
Non-controlling interests		$ 8,206	$ 35,578	$ 36,653

[1]No tax impact for the years ended December 31, 2022, 2021 and 2020.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current assets
Cash and cash equivalents	$ 878,838	$ 231,849
Restricted cash and short-term deposits	21,693	34,025
Trade accounts receivable	41,545	28,912
Inventories	692	536
Amounts due from related parties	475	3,484
Assets held for sale	721	83,044
Other current assets	314,542	543,747
Total current assets	1,258,506	925,597
Non-current assets
Restricted cash	112,350	72,048
Equity method investments	104,108	52,215
Asset under development	1,152,032	877,838
Vessels and equipment, net	1,137,053	1,264,419
Non-current assets held for sale	0	1,614,732
Non-current amounts due from related parties	3,472	0
Other non-current assets	512,039	141,446
Total assets	4,279,560	4,948,295
Current liabilities
Current portion of long-term debt and short-term debt	(344,778)	(703,170)
Trade accounts payable	(8,983)	(4,929)
Accrued expenses	(32,833)	(32,872)
Liabilities held for sale	(373)	(429,836)
Other current liabilities	(27,445)	(136,414)
Total current liabilities	(414,412)	(1,307,221)
Non-current liabilities
Long-term debt	(844,546)	(920,130)
Non-current liabilities held for sale	0	(450,068)
Other non-current liabilities	(120,428)	(92,959)
Total liabilities	(1,379,386)	(2,770,378)
EQUITY
Share capital 107,225,832 common shares of $1.00 each issued and outstanding (2021: 108,222,604)	(107,226)	(108,223)
Additional paid-in capital	(1,936,746)	(1,972,859)
Contributed surplus	(200,000)	(200,000)
Accumulated other comprehensive loss	5,811	10,834
Retained (earnings)/losses	(262,063)	539,598
Total stockholders’ equity	(2,500,224)	(1,730,650)
Non-controlling interests	(399,950)	(447,267)
Total equity	(2,900,174)	(2,177,917)
Total liabilities and equity	$ (4,279,560)	$ (4,948,295)

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
EQUITY
Common shares, shares issued (in shares)	107,225,832	108,222,604	109,943,594
Common shares, shares outstanding (in shares)	107,225,832	108,222,604	109,943,594
Common shares, par value (in dollars per share)	$ 1	$ 1

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
OPERATING ACTIVITIES
Net income/(loss)		$ 939,057	$ 560,615	$ (167,930)
Net income/(loss) from continuing operations		1,015,507	(64,774)	(25,018)
Adjustments to reconcile net income/(loss) from continuing operations to net cash provided by/(used in) operating activities:
Depreciation and amortization		51,712	55,362	55,940
Impairment of long-lived assets		76,155	0	0
Net income/(losses) from equity method investments		(19,041)	(1,080)	537
Change in fair value of investment in listed equity securities		(400,966)	295,777	0
INVESTING ACTIVITIES
Additions to equity method investments		(129,662)	(6,750)
FINANCING ACTIVITIES
Cash and cash equivalents, restricted cash and short-term deposits within assets held for sale at the beginning of period		80,869	65,316	66,988
Cash and cash equivalents, restricted cash and short-term deposits within assets held for sale at the end of period		369	80,869	65,316
Net decrease/(increase) in cash and cash equivalents, restricted cash and short-term deposits within assets held for sale		80,500	(15,553)	1,672
Net increase/(decrease) in cash and cash equivalents, restricted cash, short-term deposits and cash within assets held for sale		674,959	112,366	(117,869)
Cash and cash equivalents, restricted cash and short-term deposits at the beginning of the period		337,922	225,556	343,425
Cash and cash equivalents, restricted cash and short-term deposits at the end of the period		1,012,881	337,922	225,556
Continuing operations
OPERATING ACTIVITIES
Net income/(loss) from continuing operations		1,015,507	(64,774)	(25,018)
Adjustments to reconcile net income/(loss) from continuing operations to net cash provided by/(used in) operating activities:
Depreciation and amortization		51,712	55,362	55,940
Gain on disposal of long lived asset		0	0	(5,682)
Deconsolidation of lessor VIE		0	0	(4,809)
Impairment of long-lived assets		76,155	0	0
Amortization of deferred charges and debt guarantees, net		3,555	1,768	4,870
Net income/(losses) from equity method investments		(19,041)	(1,080)	537
Compensation cost related to employee stock awards		3,410	2,625	4,482
Net foreign exchange (gain)/losses		(1,584)	383	3,106
Change in fair value of investment in listed equity securities		(400,966)	295,777	0
Change in fair value of derivative instruments (interest rate swaps)		(72,269)	(27,016)	46,208
Change in fair value of derivative instruments (oil and gas derivatives), commodity swaps and amortization of day 1 gains		311,585	181,487	(35,150)
Change in assets and liabilities:
Trade accounts receivable		(10,917)	(3,083)	(7,658)
Inventories		(157)	86	(4)
Other current and non-current assets		(26,535)	(1,495)	(19,874)
Amounts due from related parties		367	144	9,285
Trade accounts payable		3,085	(4,648)	1,477
Accrued expenses		(4,213)	(11,957)	(7,941)
Other current and non-current liabilities	[1]	(27,470)	59,776	(36,413)
Net cash provided by continuing operations		279,054	120,381	53,656
INVESTING ACTIVITIES
Additions to asset under development		(267,421)	(213,481)	(298,304)
Additions to equity method investments		(2,447)	(8,625)	(10,231)
Proceeds from subscription of equity interest in Gimi MS		39,275	25,403	11,081
Proceeds from sale of equity method investment		97,844	0	0
Proceeds from sale of listed equity securities		625,844	0	0
Dividends received from listed equity securities		5,328	5,029	0
Cash consideration received		0	0	190,131
Short-term loan advanced to related parties		0	(1,750)	0
Net cash provided by/(used in) investing activities		498,423	(193,424)	(107,323)
FINANCING ACTIVITIES
Proceeds from short-term and long-term debt		276,640	411,866	624,901
Repayments of short-term and long-term debt		(719,917)	(289,148)	(745,445)
Net proceeds from the issuance of equity		0	0	99,831
Cash dividends paid		(55,169)	(33,136)	(26,072)
Financing costs paid		(9,599)	(13,300)	(13,300)
Purchase of treasury shares		(25,479)	(24,484)	(16,650)
Proceeds from exercise of share options		161	0	0
Net cash (used in)/provided by financing activities		(533,363)	51,798	(76,735)
Supplemental disclosure of cash flow information:
Interest paid, net of capitalized interest		74,566	35,887	54,004
Income taxes paid		1,465	694	1,181
Discontinued operations
OPERATING ACTIVITIES
Net (loss)/income from discontinued operations		76,450	(625,389)	142,912
Adjustments to reconcile net income/(loss) from continuing operations to net cash provided by/(used in) operating activities:
Depreciation and amortization		8,732	50,590	51,983
Deconsolidation of lessor VIE		(59,085)	0	0
Amortization of deferred charges and debt guarantees, net		3,932	1,280	(981)
Net income/(losses) from equity method investments		0	0	175,988
Compensation cost related to employee stock awards		239	897	938
Net foreign exchange (gain)/losses		571	82	115
Change in assets and liabilities:
Trade accounts receivable		837	1,836	3,481
Inventories		171	911	(300)
Other current and non-current assets		(5,470)	826	4,052
Amounts due from related parties		(804)	(9,563)	2,348
Trade accounts payable		(7,472)	5,598	2,355
Accrued expenses		(6,134)	18,147	11,710
Other current and non-current liabilities		(24,941)	3,999	(6,029)
Net (loss)/income from discontinued operations		(76,450)	625,389	(142,912)
Drydocking expenditure		0	(1,591)	(10,622)
Loss/(gain) on disposal and impairment of long-lived assets		105,201	(564,902)	0
Net cash (used in)/provided by discontinued operations		(60,673)	133,499	92,126
INVESTING ACTIVITIES
Additions to equity method investments		0	0	(2,410)
Dividends received from listed equity securities		0	460	10,584
Cash consideration received		569,298	119,535	0
Short-term loan advanced to related parties		0	0	(45,000)
Additions to vessels and equipment		0	(925)	(3,880)
Proceeds from repayment of short-term loan advanced to related parties		0	0	45,000
Net cash provided by discontinued investing activities		569,298	119,070	4,294
FINANCING ACTIVITIES
Proceeds from short-term and long-term debt		0	168,402	104,806
Repayments of short-term and long-term debt		(158,000)	(268,107)	(189,088)
Financing costs paid		(280)	(3,700)	(1,277)
Net cash used in discontinued financing activities		$ (158,280)	$ (103,405)	$ (85,559)

[1]Includes accretion of discount on convertible bonds of $1.7 million, $15.9 million and $15.6 million for the years ended December 31, 2022, 2021 and 2020, respectively.

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Cash Flows [Abstract]
Accretion of interest on bond	$ 1,700	$ 15,900	$ 15,600
Cash and cash equivalents	878,838	231,849	85,996
Restricted cash and short-term deposits	21,693	34,025	77,540
Restricted cash (non-current portion)	112,350	72,048	62,020
Cash, cash equivalents, restricted cash and restricted cash equivalents	$ 1,012,881	$ 337,922	$ 225,556

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Previously reported	Share Capital	Share Capital Previously reported	Treasury Shares	Treasury Shares Previously reported	Additional Paid-in Capital	Additional Paid-in Capital Previously reported	Contributed Surplus	Contributed Surplus Previously reported	Accumulated Other Comprehensive Loss	[1]	Accumulated Other Comprehensive Loss Previously reported	[1]	Retained (Losses)/Earnings	Retained (Losses)/Earnings Previously reported	Non-controlling Interests	Non-controlling Interests Previously reported
Balance at beginning of the period at Dec. 31, 2019	$ 1,750,826		$ 101,303		$ (39,098)		$ 1,876,067		$ 200,000		$ (34,866)				$ (605,145)		$ 252,565
Increase (Decrease) in Stockholders' Equity
Net (loss)/income	(167,930)														(273,557)		105,627
Dividends	(26,340)																(26,340)
Employee stock compensation	5,671						5,671
Forfeiture of employee stock compensation	(250)						(250)
Restricted stock units	0		73				(73)
Proceeds from subscription of equity interest in Gimi MS Corporation	11,081																11,081
Repurchase and cancellation of treasury shares	(16,650)		(3,500)		39,098										(52,248)
Realized accumulated comprehensive losses on disposal of investment in affiliate	0
Net proceeds from issuance of shares	100,255		12,068				88,187
Deconsolidation of lessor VIEs	(4,809)																(4,809)
Other comprehensive loss	(21,207)										(21,207)
Balance at end of the period at Dec. 31, 2020	1,630,647		109,944		0		1,969,602		200,000		(56,073)				(930,950)		338,124
Increase (Decrease) in Stockholders' Equity
Net (loss)/income	560,615														413,851		146,764
Dividends	(37,136)																(37,136)
Employee stock compensation	4,330						4,330
Forfeiture of employee stock compensation	(809)						(809)
Restricted stock units	0		264				(264)
Proceeds from subscription of equity interest in Gimi MS Corporation	25,403																25,403
Repurchase and cancellation of treasury shares	(24,484)		(1,985)												(22,499)
Realized accumulated comprehensive losses on disposal of investment in affiliate	43,380										43,380
Deconsolidation of lessor VIEs	(25,888)																(25,888)
Other comprehensive loss	45,239
Other comprehensive income	1,859										1,859
Balance at end of the period at Dec. 31, 2021	2,177,917	$ 2,177,917		$ 108,223		$ 0		$ 1,972,859		$ 200,000			$ (10,834)			$ (539,598)		$ 447,267
Increase (Decrease) in Stockholders' Equity
Net (loss)/income	939,057														787,773		151,284
Dividends	(55,169)																(55,169)
Exercise of share options	161		6				155
Employee stock compensation	3,937						3,937
Forfeiture of employee stock compensation	(157)						(157)
Restricted stock units	0		187				(187)
Proceeds from subscription of equity interest in Gimi MS Corporation	39,275																39,275
Repurchase and cancellation of treasury shares	(25,477)		(1,190)												(24,287)
Realized accumulated comprehensive losses on disposal of investment in affiliate	0
Deconsolidation of lessor VIEs	(182,707)																(182,707)
Other comprehensive loss	5,023										5,023
Balance at end of the period at Dec. 31, 2022	$ 2,900,174		$ 107,226		$ 0		$ 1,936,746		$ 200,000		$ (5,811)				$ 262,063		$ 399,950

[1]As of December 31, 2022, 2021 and 2020, our accumulated other comprehensive income/(loss) consisted of (i) $5.7 million gain, $5.0 million gain and $3.5 million loss in relation to our pension and post retirement benefit plan, (ii) $0.8 million, $nil and $nil share of equity method investment’s comprehensive losses from continuing operations, and (iii) $nil, $3.1 million and $17.7 million share of equity method investment’s comprehensive loss from discontinued operations, respectively.

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Gain/(loss) associated with pensions, net of tax	$ 5.7	$ 5	$ (3.5)
Share of equity method investment’s comprehensive losses from continuing operations	0.8	0	0
Other comprehensive loss	$ 0	$ 3.1	$ 17.7

GENERAL

GENERAL	12 Months Ended
GENERAL	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	1. GENERAL Golar LNG Limited (the “Company” or “Golar”) was incorporated in Hamilton, Bermuda on May 10, 2001 for the purpose of acquiring the liquefied natural gas (“LNG") shipping interests of Osprey Maritime Limited, which was owned by World Shipholding Limited. Our operations have evolved from LNG shipping, floating regasification, combined cycle gas fired power plants to our current focus on floating liquefaction operations. We design, construct, own and operate marine infrastructure for the liquefaction of natural gas and the regasification, storage and offloading of LNG. As of December 31, 2022, our fleet was comprised of two LNG carriers (of which one vessel is contracted for conversion to a Floating Storage Regasification Unit (“FSRU”) subject to receipt of notice to proceed and subsequent sale, the Golar Arctic ) and two FLNGs (the Hilli Episeyo (the “FLNG Hilli ” ) which is operational and the Gimi, which is currently under conversion to a FLNG). We are listed on the Nasdaq under the ticker: “GLNG”. As used herein and unless otherwise required by the context, the terms “Golar”, the “Company”, “we”, “our” and words of similar import refer to Golar or any one or more of its consolidated subsidiaries, or to all such entities.

BASIS OF PREPARATION AND SIGNIF

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	Dec. 31, 2022
Accounting Policies [Abstract]
Basis of preparation and significant accounting policies	2. BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES Basis of preparation These consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). As further discussed in note 14, during the first and second quarters of 2022, we (i) disposed of substantially all of our fleet of LNG carriers and our ship management operations to the Cool Company Ltd. (“CoolCo” and such disposal, the “CoolCo Disposal”) and (ii) sold all of the shares of our subsidiary, Golar NB13 Corporation which owns the FSRU Golar Tundra , to Asset Company 11 S.R.L (part of Italy’s SNAM group, or “Snam”) (the “TundraCo Disposal”). In November 2022, we agreed preliminary terms for the sale of our vessel operations support function in Malaysia to CoolCo (the “Golar Malaysia Disposal”), subject to CoolCo’s completion of its customary due diligence. The Golar Malaysia Disposal is expected to be completed in the second quarter of 2023. The CoolCo Disposal, the TundraCo Disposal and the Golar Malaysia Disposal all met the criteria to be classified as held for sale and were reported as discontinued operations on various dates during the year ended December 31, 2022. The related assets, liabilities, operating results and cash flows of these disposals are presented as discontinued operations for all periods presented herein. The accounting policies set out below have been applied consistently to all periods in these consolidated financial statements. Principles of consolidation A variable interest entity (“VIE”) is defined by the accounting standard as a legal entity where either (a) equity interest holders as a group lack the characteristics of a controlling financial interest, including decision-making ability and an interest in the entity’s residual risks and rewards, (b) equity interest holders have not provided sufficient equity investment to permit the entity to finance its activities without additional subordinated financial support, or (c) the voting rights of some investors are not proportional to their obligations to absorb the expected losses of the entity, their rights to receive the expected residual returns of the entity, or both and substantially all of the entity’s activities either involve or are conducted on behalf of an investor that has disproportionately few voting rights. A party that is a variable interest holder is required to consolidate a VIE if the holder has both (a) the power to direct the activities that most significantly impact the entity’s economic performance and (b) the obligation to absorb losses that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The accompanying consolidated financial statements include the financial statements of the entities listed in notes 4 and 5. Investments in entities in which we directly or indirectly hold more than 50% of the voting control are consolidated in the financial statements, as well as VIEs in which the Company is deemed to be subject to a majority of the risk of loss from the VIE’s activities or entitled to receive a majority of the VIE’s residual returns, or both. All inter-company balances and transactions are eliminated. The non-controlling interests of the above-mentioned subsidiaries were included in the consolidated balance sheets and statements of operations as “Non-controlling interests”. Changes in our ownership interest while we retain a controlling financial interest in a subsidiary are accounted for as equity transactions. The carrying amount of the non-controlling interest is adjusted to reflect our changed ownership interest, with any difference between the fair value of consideration and the amount of the adjusted non-controlling interest being recognized in equity. We recognize a gain or loss when a subsidiary issues its stock to third parties at a price per share in excess or below its carrying value resulting in a reduction in our ownership interest in the subsidiary. The gain or loss is recorded in the line “Additional paid-in capital” within the statement of changes in equity. When a consolidated subsidiary issues preferred stock, such preferred stock is classified as equity. Preferred stock issued by a consolidated subsidiary to non-controlling interests is recorded as non-controlling interests for the proceeds received upon issuance. Foreign currencies Our functional currency is the U.S. dollar as most of our revenues are received in U.S. dollars and a majority of our expenditures are incurred in U.S. dollars. Our reporting currency is U.S. dollars. Transactions in foreign currencies during the year are translated into U.S. dollars at the exchange rates in effect at the date of the transaction. Monetary assets and liabilities are translated using exchange rates at the balance sheet date. Non-monetary assets and liabilities are translated using historical exchange rates. Foreign currency transaction and translation gains or losses are included in the consolidated balance sheets and consolidated statements of operations. Use of estimates The preparation of financial statements requires management to make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of material 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. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual values, charter rates, vessel operating expenses and drydocking requirements. In relation to the oil derivative instrument (note 27), fair value is 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 FLNG Hilli’s Liquefaction Tolling Agreement (“LTA”). The fair value of the gas derivative is determined using the estimated discounted cash flows of the additional payments due to us as a result of forecasted natural gas prices and forecasted Euro/U.S. Dollar exchange rates. Significant inputs used in the valuation of the oil and gas derivative instruments include an appropriate discount rate and the length of time necessary to blend the long-term and short-term oil and gas prices obtained from quoted prices in active markets. The changes in fair value of our oil and gas derivative instruments are recognized in each period within “Realized and unrealized gains/(loss) on oil and gas derivative instruments” in the consolidated statement of operations (note 8). Fair value measurements We account for fair value measurements in accordance with ASC 820 Fair value measurement to measure assets and liabilities. The guidance provides a definition of fair value, together with a framework for measurement and requires additional disclosure about the use of fair value to measure assets and liabilities. Lease versus revenue accounting Contracts relating to our LNG carrier, FSRU and FLNG assets can take various forms including leases, tolling services and management service agreements. In addition, we have historically contracted a portion of our vessels in the spot market through the “Cool Pool” arrangement. Although the substance of these contracts is similar (they allow our counterparties to hire a managed vessel for specified consideration), the accounting treatment varies. To determine whether a contract contains a lease agreement for a period of time, the Company assesses whether, throughout the period of use, the counterparty has both of the following: • the right to obtain substantially all of the economic benefits from the use of the identified asset; and • the right to direct the use of that identified asset. If a contract relating to an asset fails to give both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e., another third party could contract for a meaningful amount of the asset capacity). In situations where we have historically provided management services unrelated to an asset contract, we account for the contract as a revenue contract. Lease accounting When a contract contains a lease, which is assessed at inception, we make an assessment of the lease classification criteria of ASC 842 Leases . An agreement will be classified as a sales-type lease for a lessor (or a finance lease for a lessee) if any of the following conditions are met at lease commencement: • ownership of the asset is transferred at the end of the lease term; • the contract contains an option to purchase the asset which is reasonably certain to be exercised; • the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the underlying asset’s useful life are not subject to this criterion; • the present value of the lease payments and any residual value guarantees present represent substantially all of the fair value of the underlying asset; and • the asset is heavily customized such that it could not be used for another use at the end of the term. If none of these criteria are met for a lessor, the lease will be classified as a direct financing lease (if the present value of the sum of the lease payments and any residual value guarantee present equals or exceeds substantially all of the fair value of the underlying asset and it is probable that the lessor will collect lease payments and any residual value guarantee), or an operating lease. If none of these criteria are met for a lessee, the lease will be classified as an operating lease. The lease term is assessed at lease commencement. The existence of any purchase options, extension options, termination options and residual value guarantees, if any are disclosed. Agreements which include extension options are included in the lease term if we believe they are reasonably certain to be exercised by the lessee. Agreements which contain purchase options and termination options are included in the lease term if we believe they are reasonably certain to not be exercised by the lessee. An extension option or a termination option is included in the lease term if the exercise of the option is controlled by the lessor. The determination of whether options are reasonably certain considers whether the option creates an economic incentive. • Lessor accounting In making the classification assessment, we have historically estimated the residual value of the underlying asset at the end of the lease term with reference to broker valuations. Generally, lease accounting commences when the asset is made available to the counterparty, however, where a contract contains specific acceptance testing conditions, lease accounting will not commence until the asset has successfully passed the acceptance tests. We assess a lease under the modification guidance when there is a change to the terms and conditions of the contract that results in a change in the scope or the consideration of the lease. For operating leases, costs directly associated with the execution of the lease or costs incurred after lease inception (the execution of the contract) but prior to the commencement of the lease that directly relates to preparing the asset for the contract (for example bunker costs), are capitalized and amortized to the consolidated statement of income over the lease term. We also defer upfront net revenue payments (for example positioning fees) for operating leases to the consolidated balance sheet and amortize to the consolidated statement of income over the lease term. Fixed revenue from operating leases is accounted for on a straight-line basis over the life of the lease; while variable revenue is accounted for as incurred in the relevant period. Fixed revenue includes fixed payments and variable payments based on a rate or index. For our operating leases for LNG carriers, we have historically elected the practical expedient to combine our service revenue and operating lease income generated from our time charter agreements as both the timing and the pattern of transfer of the components are the same. • Time charter agreements Revenues include minimum lease payments under time charters, fees for positioning and repositioning vessels, and gross pool revenues. Revenues generated from time charters, which we generally classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Initial direct costs (those directly related to the negotiation and consummation of the lease) are deferred and allocated to earnings over the lease term. Rental income and expense are amortized over the lease term on a straight-line basis. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is off-hire, 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. Revenue accounting Contracts within the scope of revenue accounting are generally those that do not contain a lease or that form part of our ordinary activities of developing and operating FLNG projects. Contracts with a customer are assessed to identify the performance obligations in the contract, determine the transaction price and allocation of the transaction price to the performance obligations identified. Revenue is recognized when the performance obligations are satisfied – either over time or at a point in time and the appropriate pattern of transfer of control over time. Contract liabilities arise when the customer makes payments in advance of receiving services while contract assets arise when services are provided in advance of customer payments being received. • Liquefaction services revenue For liquefaction services revenue, the provision of liquefaction services capacity is considered a single performance obligation recognized evenly over time. We consider our services (the receipt of customer’s gas, treatment and temporary storage on board our FLNG and delivery of LNG to waiting carriers) to be a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Amounts of overproduction or underutilization is variable consideration, estimated and recognized using the output method to the extent it is probable that a significant reversal will not occur. Contractual payment terms for liquefaction services is monthly in arrears. The period between when invoicing and when payment is due is not significant. • Services revenue Services revenue is generated from services rendered which includes but not limited to performing drydocking, site commissioning, hook-up services, FLNG studies and other services. • Management fees Management fees are generated from vessel management, which includes commercial and technical vessel-related services, ship operations and maintenance services and administrative services. The management services we provide are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services as a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount that we have the right to invoice. Our contracts generally have an initial term of one year or less, after which the arrangement continues until the end of the contract. • Cool Pool Pool revenues and expenses under the Cool Pool arrangement are accounted for in accordance with the guidance for collaborative arrangements when two (or more) parties are active participants in the activity and are exposed to significant risks and rewards dependent on the commercial success of the activity. Active participation is deemed to occur when participating on the Cool Pool steering committee. When accounting for a collaborative arrangement, we present our share of net income earned under the Cool Pool across a number of lines in the consolidated statement of operations. Net revenue and expenses incurred specifically to Golar vessels and for which we are deemed to be the principal, are presented gross on the face of the consolidated statement of operations in the line items “Time and voyage charter revenues” and “Voyage, charterhire and commission expenses.” Pool net revenues, generated by the other participants in the pooling arrangement, will be presented separately in revenue and expenses from collaborative arrangements. Each participant’s share of the net pool revenues is based on the number of days such vessels participated in the pool. Refer to note 28 for an analysis of the impact on the consolidated statement of operations for the pooling arrangement. Absent the presence of a collaborative arrangement, we present our gross share of income earned and costs incurred under the Cool Pool on the face of the consolidated statement of operations in the line items “Time and voyage charter revenues” and “Voyage, charterhire and commission expenses” respectively. For pool net revenues and expenses generated by the other participants in the pooling arrangement, we analogize these to be either the cost of obtaining a contract or the benefit of operating within the Cool Pool, and presented within the line item “Voyage, charterhire and commission expenses, net.” Leases as lessee We determine if an arrangement contains a lease at inception. Operating leases where we are the lessee result in recognition of a right-of use (“ROU”) asset with a corresponding lease liability. The ROU asset is included in balance sheet line-items ‘Other current assets’ and ‘Other non-current assets’, depending on its maturity and the lease liability is included in balance sheet line-items ‘Other current liabilities’ and ‘Other non-current liabilities’. The ROU asset represents our right to use an underlying asset for the lease term and the lease liability represents our obligation to make lease payments per the lease agreement. Operating leases are recognized at commencement date based on the present value of lease payments over the lease term, using our incremental borrowing rate as assessed at lease commencement date. We do not separate the lease and non-lease components; they are considered a single lease component. The impact of subsequent amendments to lease agreement terms and conditions is assessed prospectively. Insurance claims We have two main types of insurance policies, being loss of hire (“LOH”) and hull and machinery (“H&M”). LOH policies provides coverage for loss of revenue for our insured vessels and related claims are generally considered gain contingencies, which are recognized when the proceeds from our insurance syndication are realized or deemed realizable, net of any deductions where applicable. LOH is recognized on the face of the consolidated statement of operations in the line item “Other operating income/(losses)”. H&M policies protects us from damages in relation to our vessels and on-board equipment. Our insurance policies are considered loss recoveries. We recognize costs incurred at the time a loss event occurs. Insurance proceeds received from insured losses are recognized when considered probable of being recovered from the counterparty and for an amount net of any deductions that may apply. H&M costs and insurance recoveries are recognized on the face of the consolidated statement of operations in line item “Vessel operating expenses”. Cash and cash equivalents We consider all demand and time deposits and highly liquid investments with original maturities of three months or less to be equivalent to cash. Amounts are presented net of allowances for expected credit losses, which are assessed based on consideration of whether the balances have short-term maturities and whether the counterparty has an investment grade credit rating, limiting any credit exposure. Restricted cash and short-term deposits Restricted cash consists of bank deposits which may only be used to settle certain pre-arranged loans, bid bonds in respect of tenders for projects we have entered into, cash collateral required for certain swaps and other contracts which require us to restrict cash. Short-term deposits represent highly liquid deposits placed with financial institutions, primarily from our consolidated VIEs, which are readily convertible into known amounts of cash with original maturities of less than 12 months. Interest income earned on our short-term deposits are recognized on an accrual basis on the face of the consolidated statement of operations in line item “Interest income”. Amounts are presented net of allowances for expected credit losses, which are assessed based on consideration of whether the balances have short-term maturities and whether the counterparty has an investment grade credit rating, limiting any credit exposure. Trade accounts receivables Trade receivables are presented net of allowances for expected credit losses. At each balance sheet date, all potentially uncollectible accounts are assessed individually for the purpose of determining the appropriate allowance for expected credit loss. Our trade receivables have short maturities so we have considered that forecasted changes to economic conditions will have an insignificant effect on the estimate of the allowance, except in extraordinary circumstances. Allowance for credit losses Financial assets recorded at amortized cost and off-balance sheet credit exposures not accounted for as insurance (including financial guarantees) reflect an allowance for current expected credit losses (“credit losses”) over the lifetime of the instrument. The allowance for credit losses reflects a deduction to the net amount expected to be collected on the financial asset. Amounts are written off against the allowance when management believes the un-collectability of a balance is confirmed or certain. Expected recoveries will not exceed the amounts previously written-off or current credit loss allowance by financial asset category. We estimate expected credit losses based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. We have elected to calculate expected credit losses on the combined balance of both the amortized cost and accrued interest from the unpaid principal balance. Specific calculation of our credit allowances is included in the respective accounting policies included herein; all other financial assets are assessed on an individual basis calculated using the method we consider most appropriate for each asset. Inventories Inventories, which are comprised principally of fuel, are stated at the lower of cost and net realizable value. Cost is determined on a first-in, first-out basis. Equity method investments Equity method investments relate to our investments in entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but over which we do not exercise control or have the power to control their financial and operational policies. Investments in these entities are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the other parties’ participating rights. Under this method, we record our investment at cost and adjust the carrying amount for our share of the income or losses from these equity method investments subsequent to the date of the investment and report the recognized earnings or losses in income. Dividends received from an equity method investment reduce the carrying amount of the investment. When we decrease our investment in equity method investments but continue to retain significant influence, we recognize a gain or loss for the difference between proceeds and carrying amount of the investment sold in the statement of operations line item “Net income/(losses) from equity method investments”. Vessels and equipment Vessels and equipment are stated at cost less accumulated depreciation. The cost of vessels and equipment, less the estimated residual values, is depreciated on a straight-line basis over the assets’ remaining useful economic lives. Management estimates the residual values of our vessels based on broker scrap value cost of steel and aluminum times the weight of the ship noted in lightweight ton. Residual values are periodically reviewed and revised to recognize changes in conditions, new regulations or other reasons. The cost of construction of mooring equipment is capitalized and depreciated over the initial term of the related agreement. Refurbishment costs incurred during the period are capitalized as part of vessels and equipment and depreciated over the vessels’ remaining useful economic lives. Refurbishment costs are costs that appreciably increase the capacity or improve the efficiency or safety of vessels and equipment. Drydocking expenditures are capitalized when incurred and amortized over the period until the next anticipated drydocking. For vessels that are newly built or acquired, we have adopted the “built-in overhaul” method of accounting. The built-in overhaul method is based on the segregation of vessel costs into those that should be depreciated over the useful life of the vessel and those that require drydocking at periodic intervals to reflect the different useful lives of the components of the assets. The estimated cost of the drydocking component is amortized until the date of the first drydocking following acquisition, upon which the cost is capitalized and the process is repeated. When a vessel is disposed of, any unamortized drydocking expenditure is charged against income in the period of disposal. The capital costs include the addition of new equipment or modifications to the vessel which enhance or increase the operational efficiency and functionality of the vessel. These expenditures are capitalized and depreciated over the remaining useful life of the vessel. Expenditures of a routine repairs and maintenance nature that do not improve the operating efficiency or extend the useful lives of the vessels are expensed as incurred. Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRU and FLNG) 40 years Vessels - converted FSRU 20 years from conversion date Vessels - FLNG 30 years from conversion date Deferred drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years Asset under development An asset is classified as an asset under development when there is a firm commitment from us to proceed with the construction of the asset and the likelihood of conversion is virtually certain to occur. An asset under development is classified as non-current and is stated at cost. All costs incurred during the construction of the asset, including conversion installment payments, interest, supervision and technical costs are capitalized. Nonrefundable reimbursements are offset against the cost incurred for the construction of the asset. Interest costs directly attributable to construction of the asset are added to the cost of the asset. Capitalization ceases and depreciation commences once the asset is completed and available for its intended use. Interest costs capitalized Interest is capitalized on all qualifying assets that require a period of time to get ready for their intended use. Qualifying assets consist of new vessels under construction, assets under development and vessels undergoing conversion into FSRUs or FLNGs for our own use. In addition, certain equity method investments may be considered qualifying assets prior to commencement of their planned principal operation. The interest capitalized is calculated using the rate of interest on the loan to fund the expenditure or our weighted average cost of borrowings, where appropriate, from commencement of the asset development until substantially all the activities necessary to prepare the assets for its intended use are complete. If our financing plans associate a specific borrowing with a qualifying asset, we use the rate on that borrowing as the capitali z ation rate to be applied to that portion of the average accumulated expenditures for the asset provided that does not exceed the amount of that borrowing. We do not capitali z e amounts beyond the actual interest expense incurred in the period. Asset retirement obligation An asset retirement obligation (“ARO”) is a liability associated with the eventual retirement of a fixed asset. The fair value of an ARO is recorded as a liability in the period when the obligation arises. The fair value of the ARO is measured using expected future discounted cash outflows. When the liability is recognized, we also capitalize the related ARO cost by adding it to the carrying amount of the related fixed asset. Each period, the liability is increased for the change in its present value with a corresponding charge to operating expenses. Changes in the amount or timing of the estimated ARO are recorded as an adjustment to the related liability and asset. Held for sale assets and disposal group Individual assets or subsidiaries to be disposed of, by sale or otherwise in a single transaction, are classified as held for sale if all of the following criteria are met at the period end: • management, having the authority to approve the action, commits to a plan to sell the assets or subsidiaries; • the asset or subsidiaries are available for immediate sale in its (their) present condition subject only to terms that are usual and customary for such sales; • an active program to locate a buyer and other actions required to complete the plan to sell have been initiated; • the sale is probable; and • the transfer is expected to qualify for recognition as a completed sale, within one year. The term probable refers to a future sale that is likely to occur, the asset or subsidiaries (disposal group) is being actively marketed for sale at a price that is reasonable in relation to its current fair value and actions required to complete the plan indicate that it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn. A disposal group is classified as discontinued operations if either of the following criteria are met: (1) a component of an entity or group of components that has been disposed of by sale, disposed of other than by sale or is classified as held for sale that represents a strategic shift that has or will have a major effect on our financial results and operations or (2) an acquired business or non-profit activity (the entity to be sold) that is classified as held for sale on the date of the acquisition. Assets or subsidiaries held for sale are carried at the lower of their carrying

RECENTLY ISSUED ACCOUNTING STAN

RECENTLY ISSUED ACCOUNTING STANDARDS	12 Months Ended
RECENTLY ISSUED ACCOUNTING STANDARDS	Dec. 31, 2022
Accounting Changes and Error Corrections [Abstract]
Recently issued accounting standards	3. RECENTLY ISSUED ACCOUNTING STANDARDS Adoption of new accounting standards In March 2020, the FASB issued ASU 2020-04 Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, as amended by ASU 2021-01 Reference Rate Reform (Topic 848): Scope issued in January 2021 and ASU 2022-06 Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 issued in December 2022. This guidance provides temporary optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met, which are available for election until December 31, 2024. Modifications to contracts affected by the reference rate reform are under discussion with counterparties and optional expedients are expected to be used where available. In August 2020, the FASB issued ASU 2020-06 Debt – Debt with Conversion and Other Options (Topic 470) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Topic 815) . The amendments simplify the issuer’s accounting for convertible instruments and its application of the equity classification guidance. The new guidance eliminates some of the existing models for assessing convertible instruments, which results in more instruments being recognized as a single unit of account on the balance sheet and expands disclosure requirements. The new guidance simplifies the assessment of contracts in an entity’s own equity and existing Earnings Per Share guidance in ASC 260. We adopted this with effect from January 1, 2022. We adjusted the additional paid in capital as of January 1, 2022 in our consolidated statement of changes in equity as included herein. In May 2021, the FASB issued ASU 2021-04 Earnings Per Share (Topic 260), Debt—Modifications and Extinguishments (Subtopic 470-50), Compensation—Stock Compensation (Topic 718), and Derivatives and Hedging —Contracts in Entity’s Own Equity (Subtopic 815-40) . We adopted this with effect from January 1, 2022. The adoption of ASU 2021-04 had no impact on our consolidated financial statements. In July 2021, the FASB issued ASU 2021-05 Leases (Topic 842) – Lessors – Certain Leases with Variable Lease Payments . We adopted this with effect from January 1, 2022. The adoption of ASU 2021-05 has no impact on our consolidated financial statements. Accounting pronouncements that have been issued but not yet adopted The following table provides a brief description of other recent accounting standards that have been issued but not yet adopted as of December 31, 2022: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2021-08 Business Combinations (Topic 805) - Accounting for contract assets and contract liabilities from contracts with customers Requires contract assets and contract liabilities (i.e., deferred revenue) acquired in a business combination to be recognized and measured by the acquirer on the acquisition date in accordance with ASC 606. Generally, this new guidance will result in the acquirer recognizing contract assets and contract liabilities at the same amounts recorded by the acquiree (rather than having such amounts recognized by the acquirer at fair value in acquisition accounting, as has been historical practice). January 1, 2023 No impact expected as a result of the adoption of this ASU. Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2022-03 Fair Value Measurement (Topic 820) - Fair Value Measurement of Equity Securities Subject to Contractual Sale Restrictions This amendment is intended to reduce diversity in practice in the measurement of the fair value of equity securities subject to contractual sale restrictions. For entities that have investments in equity securities that are subject to contractual sale restrictions, the contractual restriction on the sale is not considered part of the unit of account of the equity security, is not considered when measuring fair value and additional disclosures are required. This amendment is required to be applied prospectively from date of adoption; early adoption is permitted. January 1, 2024 No impact currently expected as a result of the adoption of this ASU.

SUBSIDIARIES

SUBSIDIARIES	12 Months Ended
SUBSIDIARIES	Dec. 31, 2022
SUBSIDIARIES [Abstract]
Subsidiaries	4. SUBSIDIARIES The following table lists our significant subsidiaries and their purpose as of December 31, 2022. Unless otherwise indicated, we own a 100% ownership interest in each of the following subsidiaries. Name Jurisdiction of Incorporation Purpose Gimi Holding Company Limited (1) Bermuda Holding company Golar Hilli LLC (2) Marshall Islands Holding company Golar LNG Energy Limited Bermuda Holding company Golar Hilli Corporation (2) Marshall Islands Leases the Hilli Episeyo (“ FLNG Hilli”)* Golar LNG 2216 Corporation Marshall Islands Owns the Golar Arctic Golar Gandria N.V. Curaçao Owns the Golar Gandria Gimi MS Corporation (3) Marshall Islands Owns the Gimi Golar Management (Bermuda) Limited Bermuda Management company Golar Management Limited United Kingdom Management company Golar Management AS Norway Vessel management company Golar Management Malaysia Sdn. Bhd. Malaysia Vessel management company Golar Viking Management D.O.O Croatia Vessel management company (1) In July 2019, Gimi Holding Company Limited was incorporated and is wholly owned by Golar. In October 2019, Golar transferred its ownership in Gimi MS Corporation ("Gimi MS") to Gimi Holding Company Limited. (2) In February 2018, Golar Hilli LLC was incorporated with Golar as sole member. In June 2018, the FLNG Hilli was sold to a China State Shipbuilding Corporation entity (“CSSC entity”) that subsequently leased back the vessel on a bareboat charter for a term of 10 years. In July 2018, shares in Golar Hilli Corporation. (a 89% owned subsidiary of Golar Hilli LLC) were exchanged for Hilli Common Units, Series A Special Units and Series B Special Units (note 5). (3) In November 2018, Gimi MS was incorporated with Golar as sole shareholder. In February 2019, the Gimi was transferred to Gimi MS from Golar Gimi Corporation. In April 2019, First FLNG Holdings Pte. Ltd. (“First FLNG Holdings”), a wholly-owned subsidiary of Keppel Asia Infrastructure Fund, acquired a 30% share in Gimi MS (note 5). * The above table excludes mention of the lessor variable interest entity (“lessor VIE”) that we have leased a vessel from under a finance lease. The lessor VIE is a wholly-owned, newly formed special purpose vehicle (“SPV”) of a financial institution. While we do not hold any equity investments in this SPV, we have concluded that we are the primary beneficiary of this lessor VIE and accordingly have consolidated this entity into our financial results (note 5).

VARIABLE INTEREST ENTITIES ("VI

VARIABLE INTEREST ENTITIES ("VIEs")	12 Months Ended
VARIABLE INTEREST ENTITIES ("VIEs")	Dec. 31, 2022
VARIABLE INTEREST ENTITIES [Abstract]
Variable interest entities ("VIEs")	5. VARIABLE INTEREST ENTITIES 5.1 Lessor VIEs As of December 31, 2022, we leased one vessel (December 31, 2021: eight vessels) from a VIE as part of a sale and leaseback agreement. As further discussed in note 14, during the year ended December 31, 2022 , the Vessel SPA (defined below) in the CoolCo Disposal resulted in the disposals of our subsidiaries, including the disponent owners of seven vessels that were subject to these sale and leaseback agreements ( Golar Seal, Golar Crystal, Golar Bear, Golar Glacier, Golar Snow, Golar Ice and Golar Kelvin ). Consequently, this resulted in the deconsolidation of the lessor VIEs against non-controlling interest of $182.7 million on our consolidated balance sheet. In December 2021, we repurchased the Golar Tundra and terminated the sale and leaseback arrangement with China Merchants Bank Co. Ltd (“CMBL”) for $103.3 million which resulted in the deconsolidation of the lessor VIE against non-controlling interest of $25.9 million on our consolidated balance sheet. The results of the disposed disponent owners were classified as discontinued operations. Our continuing lessor VIE as of December 31, 2022, is with a CSSC. The CSSC entity is a wholly-owned, SPV (“Lessor SPV”). In this transaction, we sold our vessel, the FLNG Hilli and then subsequently leased back the vessel on a bareboat charter for a term of ten years. We have an option to repurchase the vessel at a fixed predetermined amount during its charter period and an obligation to repurchase the vessel at the end of the vessel’s lease period. While we do not hold any equity investments in the Lessor SPV, we have determined that we have a variable interest in the Lessor SPV and that the lessor entity, that owns the vessel, is the lessor VIE. Based on our evaluation of the agreements, we have concluded that we are the primary beneficiary of the lessor VIE and, accordingly, the lessor VIE is consolidated into our financial results. We did not record any gains or losses from the sale of this vessel as if continued to be reported as a vessels at its original cost in our consolidated financial statements at the time of transaction. Similarly, the effect of the bareboat charter arrangement is eliminated upon consolidation of the Lessor SPV. The equity attributable to the respective lessor VIE is included in non-controlling interests in our consolidated financial statements. As of December 31, 2022 and 2021, the respective vessels are reported under “Vessels and equipment, net” or “Non-current assets held for sale” in our consolidated balance sheets. The following table gives a summary of our sole sale and leaseback arrangement, including the repurchase option and obligation as of December 31, 2022: Vessel Effective from Lessor Sales value (in $ millions) Lease duration Next repurchase option (in $ millions) Date of next repurchase option Net repurchase obligation at end of lease term (in $ millions) End of lease term FLNG Hilli June 2018 CSSC entity 1,200.0 10 years 633.2 June 2023 300.0 June 2028 A summary of our payment obligations (excluding the repurchase option and obligation) under the bareboat charter with our sole lessor VIE as of December 31, 2022, are shown below: (in thousands of $) 2023 2024 2025 2026 2027 2028 FLNG Hilli (1) 115,954 110,779 105,348 100,044 94,741 22,841 (1) The payment obligations above include variable rental payments due under the lease based on assumed LIBOR plus a margin. The assets and liabilities of the lessor VIE that most significantly impact our consolidated balance sheets as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Assets Total Total Restricted cash and short-term deposits (note 15) 21,691 16,523 Liabilities Debt: Current portion of long-term debt and short-term debt (1) (337,547) (380,554) Long-term debt (1) (156,563) (216,313) (494,110) (596,867) (1) Where applicable, these balances are net of deferred finance charges (note 21). The most significant impact of the lessor VIE’s operations on our consolidated statements of operations and consolidated statements of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Continuing operations Statement of operations Interest expense 8,406 5,178 11,687 Statement of cash flows Net debt repayments (123,554) (97,056) (446,484) Net debt receipts 20,640 2,848 354,901 Financing costs paid — — (3,731) Discontinued operations Statement of operations Interest expense 3,814 17,492 23,046 Statement of cash flows Net debt repayments — (234,873) (104,179) Net debt receipts — 10,402 104,806 Financing costs paid — (1,568) (200) 5.2 Golar Hilli LLC In 2018, we and affiliates of Keppel Shipyard Limited (“Keppel”) and Black & Veatch Corporation (“B&V”) (together, the “Sellers"), completed the sale (the “Hilli Disposal”) to Golar LNG Partners LP (“Golar Partners”) of common units (the “Hilli Common Units”) in our consolidated subsidiary Golar Hilli LLC (“Hilli LLC”), which owns Golar Hilli Corporation (“Hilli Corp”), the disponent owner of the FLNG Hilli . Concurrently with the closing of the Hilli Disposal, we entered into the Amended and Restated Limited Liability Company Agreement of Hilli LLC (the “LLC Agreement”) on July 12, 2018. The ownership interests in Hilli LLC are represented by three classes of units: the Hilli Common Units, the Series A Special Units and the Series B Special Units. After the Hilli Disposal and as of December 31, 2022, the ownership structure of Hilli LLC is as follows: Percentage ownership interest Hilli Common Units Series A Special Units Series B Special Units Golar LNG Limited 44.6 % 89.1 % 89.1 % Golar Partners 50.0 % — % — % Keppel 5.0 % 10.0 % 10.0 % B&V 0.4 % 0.9 % 0.9 % We are the managing member of Hilli LLC and are responsible for all operational, management and administrative decisions relating to Hilli LLC’s business. We have retained sole control over the most significant activities and the greatest exposure to variability in residual returns and expected losses from the FLNG Hilli and, as a result, management has concluded that Hilli LLC is a VIE and that we are the primary beneficiary. As such, we continue to consolidate both Hilli LLC and Hilli Corp. All three classes of ownership interests in Hilli LLC have certain participating and protective rights. We reflect Golar Partners, Keppel and B&V’s ownership in Hilli LLC as non-controlling interests in our financial statements. Hilli LLC shall make distributions to holders of Hilli Common Units when, as and if declared by us; provided, however, that no distributions may be made on the Hilli Common Units on any distribution date unless Series A Distributions (defined below) and Series B Distributions (defined below) for the most recently ended quarter and any accumulated Series A Distributions and Series B Distributions in arrears for any past quarter have been or contemporaneously are being paid or provided for. Series A Special Units: The Series A Special Units of Hilli LLC rank senior to the Hilli Common Units and on par with the Series B Special Units. Upon termination of the LTA, Hilli LLC has a right to redeem the Series A Special Units from legally available funds at a redemption price of $1 (per Series A Special Unit) plus any unpaid distributions. There are no conversion features on the Series A Special Units. “Series A Distributions” reflect all incremental cash receipts by Hilli Corp during such quarter when Brent linked crude prices rise above $60 per barrel with contractually defined adjustments. Series B Special Units: The Series B Special Units of Hilli LLC rank senior to the Hilli Common Units and on par with the Series A Special Units. There are no conversion or redemption features on the Series B Special Units. Incremental returns generated from future vessel expansion capacity (currently uncontracted and excluding the exercise of additional capacity under the existing LTA) include cash receipts and contractually defined adjustments. Of such vessel expansion capacity distributions (“Series B Distributions”): • holders of Series B Special Units are entitled to 95% of these distributions; and • holders of Hilli Common Units are entitled to 5% of these distributions. Hilli Common Units: Distributions attributable to holders of Hilli Common Units are not declared until any accumulated Series A Special Units and Series B Special Units distributions have been paid. As discussed above, holders of Hilli Common Units are entitled to receive a pro rata share of 5% of the vessel expansion capacity distributions. Summarized financial information of Hilli LLC The assets and liabilities of Hilli LLC (1) that most significantly impacted our consolidated balance sheet as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Balance sheet Current assets 105,738 157,643 Non-current assets 1,481,722 1,280,217 Current liabilities (381,131) (444,352) Non-current liabilities (240,146) (270,371) (1) As Hilli LLC is the primary beneficiary of the lessor VIE (see above) the Hilli LLC balances include the lessor VIE. The most significant impacts of the lessor VIE’s operations on our consolidated statements of operations and consolidated statements of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Statement of operations Liquefaction services revenue 213,970 221,020 226,061 Realized and unrealized gain/(loss) on oil and gas derivative instruments 520,997 204,663 (42,561) Statement of cash flows Net debt repayments (123,554) (97,056) (322,304) Net debt receipts 20,640 2,848 230,721 Cash dividends paid (55,169) (33,136) (26,072) 5.3 Gimi MS Corporation In April 2019, Gimi MS entered into a subscription agreement with First FLNG Holdings, a wholly-owned subsidiary of Keppel Asia Infrastructure Fund, in respect to First FLNG Holdings’ participation in a 30% share of the Gimi (the “Subscription Agreement”). Gimi MS will construct, own and operate the Gimi and First FLNG Holdings subscribed for 30% of the total issued common share capital of Gimi MS for a subscription price equivalent to 30% of the estimated project cost. Under the Subscription Agreement, Gimi MS may call for cash from the shareholders for any future funding requirements and shareholders are required to contribute to such cash calls up to a defined cash call contribution. Concurrent with the closing of the sale of the common shares, we have determined that (i) Gimi MS is a VIE and (ii) we are the primary beneficiary and retain sole control over the most significant activities and the greatest exposure to variability in residual returns and expected losses from the Gimi . Thus, Gimi MS continues to be consolidated into our financial statements. Summarized financial information of Gimi MS The assets and liabilities of Gimi MS that most significantly impacted our consolidated balance sheet as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Balance sheet Current assets 12,460 7,107 Non-current assets 1,195,725 877,835 Current liabilities (10,666) (18,127) Non-current liabilities (516,298) (389,244) The most significant impacts of Gimi MS VIE’s operations on our consolidated statement of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Statement of cash flows Additions to asset under development 267,421 213,481 217,590 Capitalized financing costs (2,748) (5,605) (11,302) Net debt receipts 125,000 110,000 170,000 Proceeds from subscription of equity interest 39,275 25,403 11,081

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
SEGMENT INFORMATION	Dec. 31, 2022
Segment Reporting [Abstract]
Segment information	6. SEGMENT INFORMATION We provide and operate three distinct reportable segments as follows: • FLNG – This segment includes our operations of FLNG vessels or projects. We convert LNG carriers into FLNG vessels or build new FLNG vessels and subsequently contract them out to customers. We currently have one operational FLNG, the FLNG Hilli, and one undergoing conversion into a FLNG, the Gimi (note 18). • Corporate and other – This segment includes our vessel management, FSRU services for third parties, administrative services to affiliates and third parties and our corporate overhead costs. • Shipping – This segment includes our operations of the transportation of LNG carriers. We have historically operated and subsequently chartered out LNG carriers on fixed terms to charterers. A reconciliation of net income/(loss) to Adjusted EBITDA for the years ended December 31, 2022, 2021 and 2020 is as follows: (in thousands of $) 2022 2021 2020 Net income/(loss) 939,057 560,615 (167,930) Income taxes (438) 1,440 579 Income/(loss) before income taxes 938,619 562,055 (167,351) Depreciation and amortization 51,712 55,362 55,940 Impairment of long-term assets (note 19) 76,155 — — Unrealized (gain)/loss on oil and gas derivative instruments (note 8) (288,977) (179,891) 45,100 Realized and unrealized mark-to-market (gains)/losses on our investment in listed equity securities (note 9) (400,966) 295,777 — Other non-operating (income)/losses (note 9) (11,916) 66,027 (5,682) Interest income (12,225) (128) (1,479) Interest expense 19,286 34,486 39,182 (Gains)/losses on derivative instruments (note 10) (71,497) (24,348) 52,423 Other financial items, net (note 10) 5,380 (693) 557 Net (income)/loss from equity method investments (note 17) (19,041) (1,080) 537 Net loss/(income) from discontinued operations (note 14) 76,450 (625,389) 142,912 Adjusted EBITDA 362,980 182,178 162,139 Year Ended December 31, 2022 (in thousands of $) FLNG Corporate and other (2) Shipping Total results from continuing operations Statement of Operations: Total operating revenues (1) 214,825 43,230 9,685 267,740 Vessel operating expenses (58,583) (6,578) (7,641) (72,802) Voyage, charterhire and commission expenses, net (600) (34) (1,810) (2,444) Administrative (income)/expenses 22 (38,224) 102 (38,100) Project development expenses (5,335) (2,637) (45) (8,017) Realized gain on oil and gas derivative instruments (note 8) 232,020 — — 232,020 Other operating losses (15,417) — — (15,417) Adjusted EBITDA 366,932 (4,243) 291 362,980 Net income/(losses) from equity method investments — (5,193) 24,234 24,234 (1) Total operating revenues under the FLNG segment includes $0.9 million revenue from a FLNG study (note 7). (2) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Balance Sheet: Year Ended December 31, 2022 (in thousands of $) FLNG Corporate and other (1) Shipping Segment assets from continuing operations Assets held for sale Total Total assets 2,815,552 1,410,587 52,700 4,278,839 721 4,279,560 Equity method investments (note 17) — 48,669 55,439 104,108 — 104,108 Capital expenditures (note 18 and 20) 301,292 — 2,901 304,193 — 304,193 (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Year Ended December 31, 2021 (in thousands of $) FLNG Corporate and other (1) Shipping Total results from continuing operations Statement of Operations: Total operating revenues 221,020 27,777 11,476 260,273 Vessel operating expenses (51,195) (12,119) (1,052) (64,366) Voyage, charterhire and commission expenses/(income) (600) 166 (235) (669) Administrative expenses (2) (241) (34,913) (157) (35,311) Project development income/(expenses) (3,171) 507 143 (2,521) Realized gain on oil and gas derivative instruments (note 8) 24,772 — — 24,772 Adjusted EBITDA 190,585 (18,582) 10,175 182,178 Net income from equity method investments — 1,080 — — (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. (2) Included within the “Corporate and other” “administrative expenses” is $0.5 million of redundancy costs from an overhead streamlining exercise following the completion of the sale of our investments in Golar Partners and Hygo to NFE, (the “GMLP Merger” and “Hygo Merger”, respectively) (note 14). Balance Sheet: Year Ended December 31, 2021 (in thousands of $) FLNG Corporate and other (1) Shipping Segment assets from continuing operations Assets held for sale Total Total assets 2,314,342 807,276 128,901 3,250,519 1,697,776 4,948,295 Equity method investments (note 17) — 52,215 — 52,215 — 52,215 Capital expenditures (note 18) 219,582 — — 219,582 — 219,582 (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Year Ended December 31, 2020 (in thousands of $) FLNG Corporate and other (1) Shipping Total results from continuing operations Statement of Operations: Total operating revenues 226,061 20,695 14,632 261,388 Vessel operating expenses/(income) (52,104) 504 (5,652) (57,252) Voyage, charterhire and commission expenses — — (1,544) (1,544) Administrative expenses (1,672) (32,068) (636) (34,376) Project development expenses (2,793) (5,711) (112) (8,616) Realized gain on oil and gas derivative instruments (note 8) 2,539 — — 2,539 Adjusted EBITDA 172,031 (16,580) 6,688 162,139 Net income/(losses) from equity method investments — (537) — — Revenues from external customers For the years ended December 31, 2022, 2021 and 2020, revenues from the following customer accounted for over 10% of our total operating revenues: (in thousands of $) 2022 2021 2020 Perenco and SNH (1) 213,970 80 % 221,020 85 % 226,061 86 % (1) LTA with Perenco Cameroon S.A. (“Perenco”) and Société Nationale des Hydrocarbures (“SNH”), (together, the “Customer”) in relation to the FLNG Hilli (note 7). The revenue from external customers above excludes vessel and other management fees from related parties (note 28). Geographic data The following geographical data presents our revenues from customers and total assets with respect only to our FLNG, while operating under the LTA, in Cameroon. In time and voyage charters for LNG carriers, the charterer, not us, controls the routes of our vessels. These routes can be worldwide as determined by the charterers. Accordingly, our CODM do not evaluate our performance according to geographical region. Year Ended December 31, (in thousands of $) 2022 2021 2020 Cameroon Liquefaction services revenue 213,970 221,020 226,061 Total assets 1,559,158 1,408,444 1,264,085

REVENUE

REVENUE	12 Months Ended
REVENUE	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue	7. REVENUE The following table represents a disaggregation of revenue earned from contracts with customers during the years ended December 31, 2022, 2021 and 2020: Year Ended December 31, (in thousands of $) 2022 2021 2020 Base tolling fee (1) 204,501 204,501 204,501 Amortization of deferred commissioning period revenue (2) 4,120 4,120 4,220 Amortization of Day 1 gains (3) 22,608 9,712 9,950 Overproduction/underutilization (4) (20,089) 3,249 7,965 Incremental base tolling fee (5) 5,000 — — Other (6) (2,170) (562) (575) Liquefaction services revenue (10) 213,970 221,020 226,061 Management fees revenue (7) 27,916 27,411 20,695 Service revenue (8) 14,423 — — Other revenues (9) 1,746 366 — Vessel management fees and other revenues (10) 44,085 27,777 20,695 (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel, and at an increased rate when the oil price is greater than $60 per barrel. The oil price above the base rate is recognized as a derivative and included in “Realized and unrealized gain/(loss) on oil and gas derivative instruments” in the consolidated statements of operations (note 8). (2) Customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term was deferred (note 23 and 24) and recognized evenly over the contract term of the LTA. (3) Day 1 gain results from amount established on the initial recognition of the FLNG Hilli ’ s oil derivative instrument embedded in the LTA and the FLNG Hilli's gas derivative instruments pursuant to LTA Amendment 3 (note 23 and 24). These amounts were deferred on initial recognition and amortized evenly over the contract term. (4) In March 2021, we signed an agreement with the Customer (“LTA Amendment 2”), to change the contract term from one linked to fixed capacity of 500.0 billion cubic feet to one of a fixed term, terminating on July 18, 2026. This amendment also permits billing adjustments for amounts over or under the annual contracted capacity in a given contract year (“overproduction” or “underutilization”, respectively), commencing from the 2019 contract year. Amounts for overproduction were invoiced at the end of a given contract year, while amounts for underutilization (which is capped per contract year) will be a reduction against our final invoice to the Customer at the end of the LTA in July 2026. Pursuant to LTA Amendment 2, we have billed and recognized overproduction revenue in relation to excess production over contracted annual based capacity during contract years 2020 and 2021. Due to a production shortfall of the FLNG Hilli for the 2022 contract year, we recognized a non-current contract liability for this underutilization of $35.8 million (note 24). The presentation of this shortfall is bifurcated as reductions to the “Liquefaction services revenue” and "Other operating income” line items in the consolidated statements of operations amounting to $20.1 million and $15.7 million, respectively. (5) In July 2021, we entered into LTA Amendment 3 which increased the annual capacity utilization of FLNG Hilli by 0.2 million tons of LNG, for the 2022 contract year. In July 2022, the Customer exercised its option pursuant to LTA Amendment 3 for 0.2 million tons (out of 0.4 million tons) from January 2023 to the end of the LTA in July 2026. The combined effect results in annual contracted base capacity of 1.4 million tons of LNG from January 1, 2022 to the end of the LTA. The tolling fee is linked to TTF and the Euro/U.S. Dollar foreign exchange movements. The contractual floor rate is recognized in “Liquefaction services revenue” and the tolling fee above the contractual floor rate is recognized as a derivative in “Realized and unrealized gain/(loss) on oil and gas derivative instruments”, in the consolidated statements of operations (note 8). (6) “Other” comprised of accrued demurrage cost of $1.6 million (2021: $nil), which we recognized in the period in which the delay occurred. The unwinding of liquidated damages recognized prior to the commencement of the contract term of $0.6 million (2021: $0.6 million) were deferred (note 24) and released evenly over the contract term. (7) Comprised of ship management, administrative and vessel operation and maintenance services. We entered into several agreements to provide ship management and administrative services to external customers and related parties (note 14 and 28). (8) In August 2022, we entered into a development agreement with Snam to provide drydocking, site commissioning and hook-up services for the Golar Tundra (the “Development Agreement”), which it acquired from us in May 2022 (note 14.2). The Development Agreement includes contractual fixed payments recognized over the period of time that we provide the services to Snam. We assessed this to be a single performance obligation to the customer that is satisfied over time (from the period of entry into the agreement to delivery of the fully commissioned FSRU to our customer), with progress over time measured using an input method of recognition based on our efforts expended over the contract term, reflecting our past experience with comparable projects for our owned vessels, as determined using hours expended by our project team. As of December 31, 2022, we recognized services revenue and an associated contract liability of $14.4 million and $4.2 million (note 23), respectively. The remaining unsatisfied services revenue performance obligation of $4.9 million is expected to be recognized within a year. (9) Included in “Other revenues” are revenues from a FLNG study of $0.9 million which was completed in December 2022 (assessed as a single performance obligation recognized at a point in time) and sub-leasing income of $0.4 million (note 13). (10) Liquefaction services revenue and the revenue from a FLNG study of $0.9 million (within vessel management fees and other revenues) were included under our “FLNG” segment while the remaining vessel management fees and other revenues were recognized under our “Corporate and Other” segment. Contract Assets and Liabilities The following table represents our contract assets and liabilities balances as of December 31, 2022 and 2021: Year Ended December 31, (in thousands of $) 2022 2021 Contract assets 21,297 21,778 Current contract liabilities (1) (8,398) (4,221) Non-current contract liabilities (2) (3) (54,018) (14,515) Total contract liabilities (62,416) (18,736) Opening balance on January 1 (18,736) (22,856) Deferral of revenue (62,223) — Recognition of unearned revenue 18,543 4,120 Closing balance on December 31 (62,416) (18,736) (1) In August 2022, we entered into the Development Agreement and had received advance payments of $18.6 million, of which we had recognized services revenue of $14.4 million during the year ended December 31, 2022. (2) In May 2022, we entered into a sale and purchase agreement (the “Arctic SPA”) with SNAM RETE GAS S.p.A (part of Snam), pursuant to which, upon receipt of a notice to proceed, we will convert LNG carrier Golar Arctic to a FSRU, deliver, install and connect her to Snam’s mooring located offshore Italy, and following completion of commissioning activities and provisional acceptance, her eventual sale to Snam. The Arctic SPA includes contractual fixed payments (recognized over the period of time that we provide the services to Snam). As of December 31, 2022, we recognized a non-current contract liability of $7.8 million (note 24). (3) Included within “Non-current contract liabilities” is the advance payment received in relation to the Arctic SPA of $7.8 million, underutilization liability of $35.8 million and deferred commissioning revenue in relation to the Hilli of $10.4 million (note 24) . 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 3.5 years, including the components of transaction price described above.

REALIZED AND UNREALIZED GAIN_(L

REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Realized and unrealized gain/(loss) on oil and gas derivative instruments	8. REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS The realized and unrealized gain/(loss) on the oil and gas derivative instruments is comprised of the following: (in thousands of $) Year Ended December 31, 2022 2021 2020 Realized gain on FLNG Hilli’s gas derivative instrument 139,929 — — Realized gain on FLNG Hilli’s oil derivative instrument 110,696 24,772 2,539 Realized mark-to-market (“MTM”) adjustment on commodity swap derivatives (18,605) — — Realized gain on oil and gas derivative instruments, net 232,020 24,772 2,539 Unrealized gain on FLNG Hilli’s gas derivative instrument (note 20) 121,959 51,286 — (in thousands of $) Year Ended December 31, 2022 2021 2020 Unrealized MTM adjustment for commodity swap derivatives 111,703 1,665 — Unrealized gain/(loss) on FLNG Hilli’s oil derivative instrument (note 20) 55,315 126,940 (45,100) Unrealized gain/(loss) on oil and gas derivative instruments, net 288,977 179,891 (45,100) Realized and unrealized gain/(loss) on oil and gas derivative instruments (note 27) 520,997 204,663 (42,561) The realized gain/(loss) on oil and gas derivative instruments results from monthly billings above the FLNG Hilli base tolling fee and the incremental capacity increase pursuant to LTA Amendment 3, whereas the unrealized gain/(loss) on oil and gas derivative instruments results from movements in forecasted oil and natural gas prices and Euro/U.S. Dollar exchange rates. 9. OTHER NON-OPERATING INCOME/(LOSSES) Other non-operating income/(losses), net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16) (1) 400,966 (295,777) — UK tax lease liability (note 29) 7,148 (71,739) — Dividend income from our investment in listed equity securities 4,768 5,588 — Gain on disposal of the LNG Croatia (2) — — 5,682 Others — 124 — Other non-operating income/(losses) 412,882 (361,804) 5,682 (1) “Investment in listed equity securities”, included in balance sheet line-item “Other current assets” (note 16), relates to our equity holding in NFE of 5.3 million and 18.6 million shares as of December 31, 2022 and 2021, respectively. During the years ended December 31, 2022 and 2021, we recognized $350.9 million unrealized MTM gains and $295.8 million unrealized MTM losses, respectively. In 2022, we sold 13.3 million of our NFE Shares (note 14.3) at a price range between $40.80 and $58.29 per share for an aggregate consideration of $625.6 million, inclusive of $3.8 million fees, which resulted in realized MTM gains of $50.1 million. There was no comparable sale of our NFE Shares during the year ended December 31, 2021. (2) In March 2019, we entered into agreements with LNG Hrvatska d.o.o. (“LNG Hrvatska”),relating to the conversion and subsequent sale of the converted carrier, LNG Croatia into a FSRU. In addition, we also entered into an agreement to operate and maintain the FSRU, LNG Croatia for a minimum of 10 years (“LNG Hrvatska O&M Agreement”). In December 2020, the converted FSRU, LNG Croatia was accepted by LNG Hrvatska and we recognized a gain on disposal of $5.7 million which comprised of cash proceeds of $193.3 million, partially offset by the carrying value of the converted vessel of $187.6 million. 10. GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET Gains/(losses) on derivative instruments, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Unrealized MTM adjustment for interest rate swap (“IRS”) derivatives 72,269 27,016 (38,601) Net interest expense on undesignated IRS derivatives (772) (2,908) (6,215) Foreign exchange gain/(loss) on terminated undesignated foreign exchange swaps — 240 (2,556) Unrealized MTM adjustment for equity derivatives — — (5,051) Gains/(losses) on derivative instruments, net 71,497 24,348 (52,423) Other financial items, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Financing arrangement fees and other related costs (1) (9,340) (1,201) (1,409) Amortization of debt guarantees 2,657 2,569 4,111 Foreign exchange gain/(loss) on operations 1,598 (384) (3,107) Other (295) (291) (152) Other financials items, net (5,380) 693 (557) (1) Financing arrangement fees and other related costs for the year ended December 31, 2022 mainly comprised of (i) $4.9 million write-off of deferred financing fees and expenses in relation to an undrawn corporate bilateral facility, the availability of which expired in June 2022; (ii) $2.3 million loss on partial repurchase of the Unsecured Bonds (note 21) in December 2022 (note 21); and (iii) $1.4 million commitment fees paid in relation to the undrawn portion of the Corporate RCF, which was canceled in November 2022 (note 21).

OTHER NON-OPERATING INCOME_(LOS

OTHER NON-OPERATING INCOME/(LOSSES)	12 Months Ended
OTHER NON-OPERATING INCOME/(LOSSES)	Dec. 31, 2022
Other Income and Expenses [Abstract]
Other non-operating income/(loss)	8. REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS The realized and unrealized gain/(loss) on the oil and gas derivative instruments is comprised of the following: (in thousands of $) Year Ended December 31, 2022 2021 2020 Realized gain on FLNG Hilli’s gas derivative instrument 139,929 — — Realized gain on FLNG Hilli’s oil derivative instrument 110,696 24,772 2,539 Realized mark-to-market (“MTM”) adjustment on commodity swap derivatives (18,605) — — Realized gain on oil and gas derivative instruments, net 232,020 24,772 2,539 Unrealized gain on FLNG Hilli’s gas derivative instrument (note 20) 121,959 51,286 — (in thousands of $) Year Ended December 31, 2022 2021 2020 Unrealized MTM adjustment for commodity swap derivatives 111,703 1,665 — Unrealized gain/(loss) on FLNG Hilli’s oil derivative instrument (note 20) 55,315 126,940 (45,100) Unrealized gain/(loss) on oil and gas derivative instruments, net 288,977 179,891 (45,100) Realized and unrealized gain/(loss) on oil and gas derivative instruments (note 27) 520,997 204,663 (42,561) The realized gain/(loss) on oil and gas derivative instruments results from monthly billings above the FLNG Hilli base tolling fee and the incremental capacity increase pursuant to LTA Amendment 3, whereas the unrealized gain/(loss) on oil and gas derivative instruments results from movements in forecasted oil and natural gas prices and Euro/U.S. Dollar exchange rates. 9. OTHER NON-OPERATING INCOME/(LOSSES) Other non-operating income/(losses), net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16) (1) 400,966 (295,777) — UK tax lease liability (note 29) 7,148 (71,739) — Dividend income from our investment in listed equity securities 4,768 5,588 — Gain on disposal of the LNG Croatia (2) — — 5,682 Others — 124 — Other non-operating income/(losses) 412,882 (361,804) 5,682 (1) “Investment in listed equity securities”, included in balance sheet line-item “Other current assets” (note 16), relates to our equity holding in NFE of 5.3 million and 18.6 million shares as of December 31, 2022 and 2021, respectively. During the years ended December 31, 2022 and 2021, we recognized $350.9 million unrealized MTM gains and $295.8 million unrealized MTM losses, respectively. In 2022, we sold 13.3 million of our NFE Shares (note 14.3) at a price range between $40.80 and $58.29 per share for an aggregate consideration of $625.6 million, inclusive of $3.8 million fees, which resulted in realized MTM gains of $50.1 million. There was no comparable sale of our NFE Shares during the year ended December 31, 2021. (2) In March 2019, we entered into agreements with LNG Hrvatska d.o.o. (“LNG Hrvatska”),relating to the conversion and subsequent sale of the converted carrier, LNG Croatia into a FSRU. In addition, we also entered into an agreement to operate and maintain the FSRU, LNG Croatia for a minimum of 10 years (“LNG Hrvatska O&M Agreement”). In December 2020, the converted FSRU, LNG Croatia was accepted by LNG Hrvatska and we recognized a gain on disposal of $5.7 million which comprised of cash proceeds of $193.3 million, partially offset by the carrying value of the converted vessel of $187.6 million. 10. GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET Gains/(losses) on derivative instruments, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Unrealized MTM adjustment for interest rate swap (“IRS”) derivatives 72,269 27,016 (38,601) Net interest expense on undesignated IRS derivatives (772) (2,908) (6,215) Foreign exchange gain/(loss) on terminated undesignated foreign exchange swaps — 240 (2,556) Unrealized MTM adjustment for equity derivatives — — (5,051) Gains/(losses) on derivative instruments, net 71,497 24,348 (52,423) Other financial items, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Financing arrangement fees and other related costs (1) (9,340) (1,201) (1,409) Amortization of debt guarantees 2,657 2,569 4,111 Foreign exchange gain/(loss) on operations 1,598 (384) (3,107) Other (295) (291) (152) Other financials items, net (5,380) 693 (557) (1) Financing arrangement fees and other related costs for the year ended December 31, 2022 mainly comprised of (i) $4.9 million write-off of deferred financing fees and expenses in relation to an undrawn corporate bilateral facility, the availability of which expired in June 2022; (ii) $2.3 million loss on partial repurchase of the Unsecured Bonds (note 21) in December 2022 (note 21); and (iii) $1.4 million commitment fees paid in relation to the undrawn portion of the Corporate RCF, which was canceled in November 2022 (note 21).

GAINS_(LOSSES) ON DERIVATIVE IN

GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gains/(losses) on derivative instruments and other financial items, net	8. REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS The realized and unrealized gain/(loss) on the oil and gas derivative instruments is comprised of the following: (in thousands of $) Year Ended December 31, 2022 2021 2020 Realized gain on FLNG Hilli’s gas derivative instrument 139,929 — — Realized gain on FLNG Hilli’s oil derivative instrument 110,696 24,772 2,539 Realized mark-to-market (“MTM”) adjustment on commodity swap derivatives (18,605) — — Realized gain on oil and gas derivative instruments, net 232,020 24,772 2,539 Unrealized gain on FLNG Hilli’s gas derivative instrument (note 20) 121,959 51,286 — (in thousands of $) Year Ended December 31, 2022 2021 2020 Unrealized MTM adjustment for commodity swap derivatives 111,703 1,665 — Unrealized gain/(loss) on FLNG Hilli’s oil derivative instrument (note 20) 55,315 126,940 (45,100) Unrealized gain/(loss) on oil and gas derivative instruments, net 288,977 179,891 (45,100) Realized and unrealized gain/(loss) on oil and gas derivative instruments (note 27) 520,997 204,663 (42,561) The realized gain/(loss) on oil and gas derivative instruments results from monthly billings above the FLNG Hilli base tolling fee and the incremental capacity increase pursuant to LTA Amendment 3, whereas the unrealized gain/(loss) on oil and gas derivative instruments results from movements in forecasted oil and natural gas prices and Euro/U.S. Dollar exchange rates. 9. OTHER NON-OPERATING INCOME/(LOSSES) Other non-operating income/(losses), net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16) (1) 400,966 (295,777) — UK tax lease liability (note 29) 7,148 (71,739) — Dividend income from our investment in listed equity securities 4,768 5,588 — Gain on disposal of the LNG Croatia (2) — — 5,682 Others — 124 — Other non-operating income/(losses) 412,882 (361,804) 5,682 (1) “Investment in listed equity securities”, included in balance sheet line-item “Other current assets” (note 16), relates to our equity holding in NFE of 5.3 million and 18.6 million shares as of December 31, 2022 and 2021, respectively. During the years ended December 31, 2022 and 2021, we recognized $350.9 million unrealized MTM gains and $295.8 million unrealized MTM losses, respectively. In 2022, we sold 13.3 million of our NFE Shares (note 14.3) at a price range between $40.80 and $58.29 per share for an aggregate consideration of $625.6 million, inclusive of $3.8 million fees, which resulted in realized MTM gains of $50.1 million. There was no comparable sale of our NFE Shares during the year ended December 31, 2021. (2) In March 2019, we entered into agreements with LNG Hrvatska d.o.o. (“LNG Hrvatska”),relating to the conversion and subsequent sale of the converted carrier, LNG Croatia into a FSRU. In addition, we also entered into an agreement to operate and maintain the FSRU, LNG Croatia for a minimum of 10 years (“LNG Hrvatska O&M Agreement”). In December 2020, the converted FSRU, LNG Croatia was accepted by LNG Hrvatska and we recognized a gain on disposal of $5.7 million which comprised of cash proceeds of $193.3 million, partially offset by the carrying value of the converted vessel of $187.6 million. 10. GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET Gains/(losses) on derivative instruments, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Unrealized MTM adjustment for interest rate swap (“IRS”) derivatives 72,269 27,016 (38,601) Net interest expense on undesignated IRS derivatives (772) (2,908) (6,215) Foreign exchange gain/(loss) on terminated undesignated foreign exchange swaps — 240 (2,556) Unrealized MTM adjustment for equity derivatives — — (5,051) Gains/(losses) on derivative instruments, net 71,497 24,348 (52,423) Other financial items, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Financing arrangement fees and other related costs (1) (9,340) (1,201) (1,409) Amortization of debt guarantees 2,657 2,569 4,111 Foreign exchange gain/(loss) on operations 1,598 (384) (3,107) Other (295) (291) (152) Other financials items, net (5,380) 693 (557) (1) Financing arrangement fees and other related costs for the year ended December 31, 2022 mainly comprised of (i) $4.9 million write-off of deferred financing fees and expenses in relation to an undrawn corporate bilateral facility, the availability of which expired in June 2022; (ii) $2.3 million loss on partial repurchase of the Unsecured Bonds (note 21) in December 2022 (note 21); and (iii) $1.4 million commitment fees paid in relation to the undrawn portion of the Corporate RCF, which was canceled in November 2022 (note 21).

INCOME TAXES

INCOME TAXES	12 Months Ended
INCOME TAXES	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income taxes	11. INCOME TAXES The components of income tax benefit/(expense) are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Current tax expense (520) (1,445) (375) Deferred tax benefit/(expense) 958 5 (204) Total income tax benefit/(expense) 438 (1,440) (579) The income taxes for the years ended December 31, 2022, 2021 and 2020 differed from the amount computed by applying the Bermuda statutory income tax rate of 0% as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Effect of movement in deferred tax balances 958 5 (204) Effect of adjustments in respect of current tax in prior periods 346 (232) 40 Effect of taxable income in various countries (866) (1,213) (415) Total tax benefit/(expense) 438 (1,440) (579) Jurisdictions open to examination The earliest tax years that remain subject to examination by the major taxable jurisdictions in which we operate are: 2021 (UK and Croatia), 2018 (Norway) and 2019 (Mauritania/Senegal). Deferred taxes Deferred income taxes reflect the impact of temporary differences between the amount of assets and liabilities recognized for financial reporting purposes and such amounts recognized for tax purposes and pensions. As of December 31, 2022, we have a deferred tax liability of $0.4 million (2021: $0.6 million).

EARNINGS_(LOSS) PER SHARE

EARNINGS/(LOSS) PER SHARE	12 Months Ended
EARNINGS/(LOSS) PER SHARE	Dec. 31, 2022
Earnings Per Share [Abstract]
Earnings/(loss) per share	12. EARNINGS/(LOSS) PER SHARE Basic earnings/(loss) per share (“EPS”)/(“LPS”) is calculated with reference to the weighted average number of common shares outstanding during the year. The components of the numerator for the calculation of basic and diluted EPS/(LPS) are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Net income/(loss) net of non-controlling interests - continuing operations - basic and diluted 872,429 (175,960) (93,991) Net (loss)/income net of non-controlling interests - discontinued operations - basic and diluted (84,656) 589,811 (179,566) The components of the denominator for the calculation of basic and diluted EPS/(LPS) are as follows: Year ended December 31, (in thousands) 2022 2021 2020 Basic: Weighted average number of common shares outstanding 107,860 109,644 97,554 Dilutive: Dilutive impact of share options and RSUs (1) 682 — — Weighted average number of common shares outstanding 108,542 109,644 97,554 EPS/(LPS) per share are as follows: Year ended December 31, 2022 2021 2020 Basic EPS/(LPS) from continuing operations $ 8.09 $ (1.60) $ (0.96) Diluted EPS/(LPS) from continuing operations (1) $ 8.04 $ (1.60) $ (0.96) Basic and diluted EPS from discontinued operations $ (0.79) $ 5.38 $ (1.84) (1) The effects of stock awards and convertible bonds have been excluded from the calculation of diluted EPS/LPS from continuing operations for the years ended December 31, 2021 and 2020 because the effects were anti-dilutive.

OPERATING LEASES

OPERATING LEASES	12 Months Ended
OPERATING LEASES	Dec. 31, 2022
Leases [Abstract]
Operating leases	13. OPERATING LEASES Rental income The minimum contractual future revenues to be received on a time charter agreement in respect of the Golar Arctic as of December 31, 2022, are as follows: Year ending December 31 (in thousands of $) 2023 15,420 Total minimum contractual future revenues 15,420 The cost and accumulated depreciation, including impairment of the Golar Arctic, leased to third parties at December 31, 2022 and 2021 were $196.0 million and $196.0 million; and $152.3 million and $72.8 million, respectively. The components of operating lease income were as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Operating lease income 8,857 11,476 13,887 Variable lease income (1) 828 — 745 Total operating lease income (2) 9,685 11,476 14,632 (1) “Variable lease income” is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases. (2) Total operating lease income is presented in the consolidated statement of operations line item “Time and voyage charter revenues” Rental expense We lease certain office premises, equipment on-board our fleet of vessels and service boats supporting the FLNG Hilli under operating leases. Many lease agreements include one or more options to renew. We will include these renewal options when we are reasonably certain that we will exercise the option. The exercise of these lease renewal options is at our discretion. Variable lease cost relates to certain of our lease agreements which include payments that vary. These are primarily generated from service charges related to our usage of office premises, usage charges for equipment on-board our fleet of vessels, adjustments for inflation, and fuel consumption for the rental of service boats supporting the FLNG Hilli . The components of operating lease cost were as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Operating lease cost 4,160 5,899 4,338 Variable lease cost (1) 1,479 1,621 4,000 Total operating lease cost (2) 5,639 7,520 8,338 (1) “Variable lease cost” is excluded from lease payments that comprise the operating lease liability. (2) Total operating lease cost is included in the consolidated statement of operations line-items “Vessel operating expenses” and “Administrative expenses”. As of December 31, 2022 and 2021 the right-of-use assets recognized by Golar as a lessee in various operating leases amounted to $5.7 million and $10.3 million respectively (note 20). In connection with the CoolCo Disposal, we modified the terms of certain agreements in relation to our office premises and equipment on-board our fleet of vessels which reduced our minimum lease payments to $5.1 million as of December 31, 2022 compared to $7.9 million for the same period in 2021 . The weighted average remaining lease term for our operating leases is 4.8 years (2021: 5.0 years). Our weighted-average discount rate applied for most of our operating leases is 5.5% (2021: 5.5%). The maturity of our lease liabilities is as follows: Year ending December 31 (in thousands of $) 2023 1,328 2024 851 2025 1,151 2026 1,088 2027 and thereafter 730 Total minimum lease payments 5,148 During the year ended December 31, 2022, we entered into an agreement to sub-lease one of our offices and recognized $0.4 million and $4 thousand in the consolidated statement of operations line-item “Vessel management fees and other revenues” and “Administrative expenses”, respectively . The minimum contractual future revenues to be received in respect of the sublet office space is $0.1 million.

ASSETS AND LIABILITIES HELD FOR

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
Assets and liabilities held for sale and discontinued operations	14. ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS The net income/(loss) from discontinued operations for the years ended December 31, 2022, 2021 and 2020 are as follows: Year Ended December 31, 2022 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total (Loss)/income from discontinued operations (194,500) 4,880 — (189,620) (Loss)/ gain on disposal (10,060) 123,230 — 113,170 Net (loss)/income from discontinued operations (204,560) 128,110 — (76,450) Year Ended December 31, 2021 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total (Loss)/income from discontinued operations 54,534 2,806 (6,892) 50,448 Gain on disposal — — 574,941 574,941 Net income from discontinued operations 54,534 2,806 568,049 625,389 Year Ended December 31, 2020 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total Income/(loss) from discontinued operations 36,699 (3,622) (175,989) (142,912) Net income/(loss) from discontinued operations 36,699 (3,622) (175,989) (142,912) 14.1 The CoolCo Disposal On January 26, 2022, we entered into a share purchase agreement and related agreements with CoolCo, as amended on February 25, 2022 (the “Vessel SPA ” ), pursuant to which CoolCo acquired all of the outstanding shares of nine of our wholly-owned subsidiaries. Eight of these entities, Golar Hull M2021 Corp., Golar Hull M2022 Corp., Golar Hull M2027 Corp., Golar LNG NB12 Corporation, Golar LNG NB10 Corporation, Golar Hull M2047 Corp., Golar Hull M2048 Corp., and Golar LNG NB11 Corporation are each the registered or disponent owner of the following modern LNG carriers: Golar Seal, Golar Crystal, Golar Bear, Golar Frost, Golar Glacier, Golar Snow, Golar Ice and Golar Kelvin . The Cool Pool Limited is the entity responsible for the marketing of these LNG carriers. The purchase price agreed for each LNG carrier recognized as an asset in the respective subsidiaries was stated as $145.0 million , subject to working capital and debt adjustments arising from the residual balances of each wholly owned subsidiary as of the respective completion date of each subsidiary disposal. On January 26, 2022, we also entered into the Transitional Services Agreement (the “CoolCo TSA”) with CoolCo, pursuant to which we agreed to provide corporate administrative services to CoolCo for a fixed daily fee an agreement in principle with CoolCo that, following the conclusion of an internal restructuring of our management business, CoolCo will acquire the management entities that are responsible for the commercial and technical vessel management of the LNG carriers acquired by CoolCo and the LNG carriers and FSRU that Golar has been managing for third parties (the “ManCo Agreement ”, or our shipping and FSRU management business) . Each subsidiary disposal was closed with phased completion dates corresponding with the date that the respective subsidiary debt was either refinanced or assumed by CoolCo and customary conditions precedent were met. Although the disposals to CoolCo closed in stages from March 3, 2022 to June 30, 2022, t he disposals to CoolCo are considered a disposal group and the associated assets and liabilities of the disposal group were classified as held-for-sale and qualified as a discontinued operation on March 1, 2022, when the strategic shift criterion in ASC 205 was met. Consequently, we retrospectively reclassified the results of the disposal group and separately presented as “Net income/(loss) from discontinued operations”. Each of the subsidiaries were de-recognized on the respective dates of each disposal with a corresponding recognition of a (loss)/gain on disposal. In November 2022, CoolCo and us agreed for CoolCo to acquire our vessel operations business in Malaysia, subject to the satisfaction of customary closing condit ions which is expected to complete in the first half of 2023. The associated assets and liabilities of our Malaysia vessel operations were classified as held-for-sale and qualified as a discontinued operation on December 31, 2022. As such we have we have retrospectively reclassified the results as “Net income/(loss) from discontinued operations”. As of December 31, 2022, we hold 8.3% share in Cool Co and we continued to account for our investment in CoolCo under the equity method of accounting (note 17). The discontinued operations were previously included in two of our three segments, “Shipping” (containing the business activities of the LNG carriers and The Cool Pool Limited), and “Corporate and Other” (containing our shipping and FSRU management and finance operations business). Our continuing involvement with the discontinued operations of the disposal group includes: • our equity method investment in CoolCo (note 17); • the financial guarantees we provide to CoolCo with respect to the debt assumed by CoolCo related to the Golar Kelvin and Golar Ice , in place until the earlier of the repayment of the vessel debt by CoolCo or until release by the lessors (note 28); • undrawn $25.0 million revolving credit facility committed per the loan agreement to be made available until January 2024 (note 28); • CoolCo's management of our LNG carrier Golar Arctic and FSRU Golar Tundra (note 28); • our agreements with CoolCo that sub-contract our contractual vessel management obligations for the LNG Croatia pursuant to our Operation and Maintenance Agreement with LNG Hrvastska d.o.o. (the “LNG Hrvatska O&M Agreement”) and for New Fortress Energy Inc.'s (“NFE's”) fleet of vessels and the eight vessels that was subsequently sold to Energos Infrastructure Management LLC (“Energos”) in August 2022 (further disclosed in note in 14.3 Disposal of Golar Partners and Hygo below and note 28); and • our provision of IT services, routine accounting services, treasury services, finance operation services, and any additional services reasonably required pursuant to the CoolCo ASA (note 28). The following table contains the financial statement line-items presented as discontinued operations following the CoolCo Disposal: Year ended December 31, (in thousands of $) 2022 2021 2020 Time and voyage charter revenues 37,289 161,957 164,740 Vessel and other management fees 1,815 — — Vessel operating expenses (8,466) (49,446) (46,400) Voyage, charterhire and commission expenses (1,229) (709) (11,228) Administrative expenses 1,906 476 (772) Project development expenses (62) (362) (275) Depreciation and amortization (5,807) (43,497) (44,437) Impairment of long-lived assets (1) (218,349) — — Other operating income 4,374 5,020 3,262 Operating (loss)/income (188,529) 73,439 64,890 Other non-operating losses — (124) — Interest income 4 7 67 Interest expense (4,725) (18,087) (26,954) Other financial items, net (799) (401) (902) Pretax (loss)/income from discontinued operations (194,049) 54,834 37,101 Income taxes (451) (300) (402) (Loss)/income from discontinued operations (194,500) 54,534 36,699 Loss on CoolCo Disposal (2) (10,060) — — Net (loss)/income from discontinued operations (204,560) 54,534 36,699 (1) Impairment of long-live assets relates to the impairment charge on the held for sale vessels recognized in accordance with ASC 360 Property, plant and equipment , following their classification as held-for-sale. (2) Loss on CoolCo Disposal comprised of carrying values of the assets and liabilities disposed of $355.4 million, partially offset by the proceeds received of $218.2 million cash consideration and 12.5 million shares of CoolCo valued at $127.1 million (based on the respective share price on the phased completion dates). The following table contains the financial statement line-items forming the assets and liabilities classified as held for sale: (in thousands of $) 2022 2021 ASSETS Current assets Cash and cash equivalents 369 34,173 Restricted cash and short-term deposits — 43,311 Trade accounts receivable 16 767 Other current assets 29 1,965 Total current assets held for sale 414 80,216 Non-current assets Restricted cash — 780 Vessels and equipment, net 51 1,383,760 Other non-current assets 151 697 Total non-current assets held for sale 202 1,385,237 Total assets held for sale 616 1,465,453 LIABILITIES Current liabilities Current portion of long-term debt and short-term debt — (338,501) Trade accounts payables (3) (7,272) Accrued expenses (180) (59,246) Other current liabilities (76) (11,640) Total current liabilities held for sale (259) (416,659) Non-current liabilities Long-term debt — (292,322) Other non-current liabilities (114) (11,978) Total non-current liabilities held for sale (114) (304,300) Total liabilities held for sale (373) (720,959) 14.2 The TundraCo Disposal On May 31, 2022 we entered into a share purchase agreement with Snam pursuant to which it acquired 100% of the share capital of our subsidiary Golar LNG NB 13 Corporation, owner of FSRU Golar Tundra for $352.5 million. The assets and liabilities of the Golar Tundra met the criteria for presentation as held-for-sale and also qualified as a discontinued operation on May 30, 2022. Consequently, we retrospectively reclassified the results of the Golar Tundra and separately presented as “Net income/(loss) from discontinued operations”. The discontinued operations were previously included in the “Shipping” segment. Our continuing involvement with the discontinued operations of the Golar Tundra includes: • the Development Agreement (note 7); and • management fees of $0.7 million. The following table contains the financial statement line-items presented as discontinued operations following TundraCo's Disposal: Year ended December 31, (in thousands of $) 2022 2021 2020 Time and voyage charter revenues 27,776 29,534 12,509 Vessel operating expenses (5,119) (6,511) (5,274) Voyage, charterhire and commission expenses (10,004) (9,396) 138 Administrative expenses (16) (89) (163) Depreciation and amortization (2,955) (7,092) (7,546) Operating income/(loss) 9,682 6,446 (336) Interest income — 4 27 Interest expense (4,649) (2,589) (3,219) Other financial items, net (153) (1,055) (94) Pretax income/(loss) from discontinued operations 4,880 2,806 (3,622) Income taxes — — — Income/(loss) from discontinued operations 4,880 2,806 (3,622) Gain on disposal of discontinued operations (1) 123,230 — — Net income/(loss) from discontinued operations 128,110 2,806 (3,622) (1) Gain on TundraCo Disposal comprised of (i) cash proceeds received of $352.5 million, (ii) a partially offset by the net asset value of Golar LNG NB 13 Corporation of $229.0 million and (iii) related fees incurred in relation to disposal of $0.3 million. The following table contains the financial statement line-items forming the assets and liabilities classified as held for sale: (in thousands of $) 2022 2021 ASSETS Current assets Cash and cash equivalents — 2,605 Trade accounts receivable — 70 Other current assets 105 153 Total current assets held for sale 105 2,828 Non-current assets Vessels and equipment, net — 229,495 Total non-current assets held for sale — 229,495 Total assets held for sale 105 232,323 (in thousands of $) 2022 2021 LIABILITIES Current liabilities Current portion of long-term debt and short-term debt — (9,911) Trade accounts payables — (204) Accrued expenses — (737) Other current liabilities — (2,325) Total current liabilities held for sale — (13,177) Non-current liabilities Long-term debt — (145,768) Total non-current liabilities held for sale — (145,768) Total liabilities held for sale — (158,945) 14.3 Golar Partners and Hygo disposals On April 15, 2021, we completed the sale of our investments in Golar Partners and Hygo to NFE. We received consideration of $876.3 million which comprised of (i) $80.8 million cash for our investment in Golar Partners and (ii) $50.0 million cash and 18.6 million Class A NFE common shares (“NFE Shares ”) valued at $745.4 million for our investment in Hygo (the “GMLP Merger ” and “Hygo Merger ” , respectively). The net income/(loss) of equity method investments from discontinued operations for the period ended April 15, 2021 and the year ended December 31, 2020 is as follows: Period January 1, 2021 to April 15, 2021 Year ended December 31, (in thousands of $) 2021 2020 Net income/(loss) from equity method investments in Golar Partners 8,116 (136,832) Net loss from equity method investments in Hygo (15,008) (39,157) Loss from discontinued operations (6,892) (175,989) Gain on disposal of equity method investments (1) 574,939 — Net income/(loss) from discontinued operations 568,047 (175,989) (1) Gain on disposal of discontinued operations comprised of (i) proceeds received of $876.3 million; (ii) release of our tax indemnity guarantee liability to Golar Partners of $2.0 million; (iii) a partial offset by the carrying values of our investment in affiliates disposed of $257.3 million as of April 15, 2021; (iv) realized accumulated comprehensive losses on disposal of investment in affiliates of $43.4 million; and (v) fees incurred in relation to disposals of $2.7 million. The summarized financial information of Golar Partners and Hygo shown on a 100% basis are as follows: (in thousands of $) April 15, 2021 December 31, 2020 Golar Partners Hygo Golar Partners Hygo Balance Sheet Current assets 85,738 97,509 146,821 109,596 Non-current assets 1,742,835 949,265 1,880,840 917,976 Current liabilities (1,152,473) (144,146) (832,277) (97,245) Non-current liabilities (17,965) (461,291) (570,063) (453,278) Non-controlling interests (82,339) (15,250) 82,112 13,557 (in thousands of $) April 15, 2021 December 31, 2020 Golar Partners Hygo Golar Partners Hygo Statement of Operations Revenue 78,389 13,749 284,734 47,295 Net income/(loss) (1) 28,952 (110,735) 18,077 (61,859) (1) Net loss for Hygo for the period ended April 15, 2021 includes the management incentive scheme (“MIS”) of $83.7 million which is not reflected in our share of net losses of Hygo as the MIS was reimbursed by Stonepeak. Golar Partners and Hygo Post-Merger Services Agreements Upon completion of the GMLP Merger and the Hygo Merger, we entered into certain transition services agreements, corporate services agreements, ship management agreements and omnibus agreements with Golar Partners, Hygo and NFE. These agreements replaced the previous management and administrative services agreements, ship management agreements and guarantees that Golar provided to Golar Partners and Hygo. Hygo We and Stonepeak, agreed to severally indemnify NFE Brazil, NFE, Merger Sub and each of their respective affiliates and representatives, from and against any and all losses, damages, liabilities, costs, charges, fees, expenses, taxes, disbursements, actions, penalties, proceedings, claims and demands or other liabilities related to certain taxes imposed by government authorities. Golar Partners Under the omnibus agreement, Golar agreed to guarantee the certain obligations of the charters of the Methane Princess, Golar Winter, Golar Eskimo, NR Satu and maintain (i) our several guarantee in respect of the Hilli bareboat charter in accordance with the terms of the Hilli bareboat charter and (ii) the guarantee dated November 29, 2016 in favor of Standard Chartered Bank (“SCB”) issued pursuant to the facility letter between SCB and Hilli Corp. We have also agreed to maintain the indemnification for certain costs incurred in Hilli operations until August 14, 2025, when these costs exceed a contractual ceiling, capped at $20.0 million. We shall comply with all covenants and terms, including provision of covenants compliance reports, if required. We shall also indemnify, defend and hold harmless NFE and each of its affiliates from and against all losses, liabilities, damages, costs and expenses of every kind and nature, reasonable attorneys’ fees and expert's fees arising in connection with our failure to comply with the foregoing. The maximum potential exposure in respect of the guarantees issued by the Company is not known as these matters cannot be absolutely determined. The likelihood of triggering the guarantees is remote based on our past performance. For the year ended December 31, 2022 and 2021 we: • earned ship management fees amounting to $9.5 million and $6.9 million and administrative services fees amounting to $4.5 million and $3.1 million, respectively. NFE terminated the transition services and Bermuda services agreements on December 31, 2022. • incurred pool income/expense from other participants in the pooling arrangement totaling $0.5 million of income and $2.5 million of expenses, respectively; • declared distributions on Hilli LLC totaling $29.4 million and $21.2 million, respectively, with respect to the common units owned by Golar Partners and incurred $4.1 million and $0.1 million, respectively for Hilli's costs indemnification; and • earned charter and debt guarantee fees from Golar Partners and Hygo amounting to $1.7 million and $1.4 million, respectively. On August 15, 2022, NFE terminated its sale and leaseback arrangements in respect of the Golar Celsius, Golar Penguin and Golar Nanook

RESTRICTED CASH AND SHORT-TERM

RESTRICTED CASH AND SHORT-TERM DEPOSITS	12 Months Ended
RESTRICTED CASH AND SHORT-TERM DEPOSITS	Dec. 31, 2022
Restricted Cash and Investments [Abstract]
Restricted cash and short-term deposits	15. RESTRICTED CASH AND SHORT-TERM DEPOSITS Our restricted cash and short-term deposits balances are as follows: (in thousands of $) 2022 2021 Restricted cash in relation to the FLNG Hilli (1) 60,952 60,720 Restricted cash and short-term deposits held by lessor VIEs (2) 21,691 16,523 Restricted cash in relation to the Golar Arctic guarantees (3) 38,822 — Restricted cash relating to sale of LNG Croatia (4) 11,504 11,328 Restricted cash relating to office lease 1,074 2 Restricted cash related to Hygo performance guarantee (5) — 1,500 Restricted cash in relation to liability for UK tax leases (6) (note 29) — 16,000 Total restricted cash and short-term deposits 134,043 106,073 Less: Amounts included in current restricted cash and short-term deposits (21,693) (34,025) Long-term restricted cash 112,350 72,048 (1) In November 2015, in connection with the issuance of a $400 million letter of credit (“LC”) by a financial institution to the Customer of the FLNG Hilli , we recognized an initial cash collateral of $305.0 million to support the FLNG Hilli performance guarantee. Under the provisions of the LC, the terms allow for a stepped reduction in the value of the guarantee over time and a corresponding reduction to the cash collateral requirements. In May 2021, the FLNG Hilli had achieved 3.6 million tons of LNG production, reducing the LC to $100 million and the cash collateral to $61.0 million as of December 31, 2022. In November 2016, after we satisfied certain conditions precedent, the LC originally issued with an initial expiration date of December 31, 2018, was re-issued and automatically extends, on an annual basis, until the tenth anniversary of the acceptance date of the FLNG Hilli , unless the bank exercises its option to exit from the arrangement by giving a three months’notice prior to the next annual renewal date. (2) These are amounts held by lessor VIE that we are required to consolidate under U.S. GAAP into our financial statements as a VIE (note 5). (3) In connection with the Arctic SPA, we are required to provide a performance guarantee of €26.9 million and three advance repayment guarantees totaling €163.9 million, which corresponds to the three installment payments from Snam. The performance guarantee and the advance repayment guarantees secures our contractual and performance obligations of the conversion of the Golar Arctic , respectively. As of December 31, 2022, we recognized cash collateral for the performance guarantee and first of three advance repayment guarantees of $29.8 million (€26.9 million) and $9.0 million (€8.1 million), respectively. The performance guarantee and three advance repayments guarantees will remain as restricted cash until the final acceptance date of October 2027 and the provisional acceptance date of December 2025, respectively. (4) In connection with the LNG Hrvatska O&M Agreement, we are required to maintain two performance guarantees, one in the amount of €9.3 million and one in the amount of $1.3 million, both of which will remain restricted throughout the 10-year term until December 2030. (5) In connection with the disposal of Hygo, we provided a $1.5 million performance guarantee to the senior lenders of Centrais Eléctricas de Sergipe S.A. to enable those lenders to waive their requirement for consent in the event of a change of control and extend the technical completion date of the power plant. The performance guarantee was subsequently released in November 2022. (6) The lessor for the six legacy UK leases had a first priority security interest in relation to the Golar Gandria and second priority interests in relation to the Golar Tundra and the Golar Frost

OTHER CURRENT ASSETS

OTHER CURRENT ASSETS	12 Months Ended
OTHER CURRENT ASSETS	Dec. 31, 2022
Other Assets [Abstract]
Other current assets	16. OTHER CURRENT ASSETS Other current assets consists of the following: (in thousands of $) 2022 2021 Investment in listed equity securities (1) 224,788 450,225 MTM asset on TTF linked commodity swap derivatives (note 27) 73,583 1,753 Receivable from TTF linked commodity swap derivatives 4,638 — Interest receivable from money market deposits 3,617 — Prepaid expenses 2,760 2,692 Receivable from IRS derivatives 1,923 — TTF linked commodity swap collateral (2) — 6,940 Gas derivative instrument (note 27) — 79,578 Other receivables (3) 3,233 2,559 Other current assets 314,542 543,747 (1) “Investment in listed equity securities” as of December 31, 2022 and 2021 comprised of our 5.3 million and 18.6 million NFE Shares, and associated dividend receivable of $nil and $0.6 million, respectively. Dividend receivable is presented in the consolidated statement of operations line-item “Other non-operating income/(losses)”. (2) “TTF linked commodity swap collateral” relates to the cash amount required by the swap counterparty, held at measurement date, which is reactive to the daily fluctuations of the market value of the financial instrument. (3) Included in “Other receivables” as of December 31, 2022 is $1.8 million reimbursable from Snam in relation to the Development Agreement.

EQUITY METHOD INVESTMENTS

EQUITY METHOD INVESTMENTS	12 Months Ended
EQUITY METHOD INVESTMENTS	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity method investments	17. EQUITY METHOD INVESTMENTS At December 31, 2022 and 2021, we have the following participation in investments that are recorded using the equity method: 2022 2021 Egyptian Company for Gas Services S.A.E (“ECGS”) 50.0 % 50.0 % Avenir LNG Limited (“Avenir”) 23.5 % 23.5 % CoolCo 8.3 % — % Aqualung Carbon Capture AS (“Aqualung”) 4.4 % — % The carrying amounts of our equity method investments as of December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 CoolCo 55,439 — Avenir 41,790 47,913 ECGS 4,503 4,302 Aqualung 2,376 — Equity method investments 104,108 52,215 The components of our equity method investments are as follows: (in thousands of $) 2022 2021 Balance as of January 1, 52,215 44,385 Additions 129,662 6,750 Net income 19,041 1,080 Guarantee fee 1,708 — Employee stock compensation 127 — Share of other comprehensive losses (797) — Proceeds from disposal (97,848) — Balance as of December 31, 104,108 52,215 CoolCo In January 2022, we entered into the Vessel SPA with CoolCo, as further described in note 14.1. In November 2022, we sold 8.0 million of our CoolCo shares or 11.2% at NOK 130 per share for net consideration of $97.9 million, inclusive of $1.5 million fees. Concurrent with the sale of our CoolCo shares, CoolCo announced a private placement of 13.7 million new shares at NOK 130 per share which further diluted our interest in CoolCo. Following our sale of CoolCo shares and CoolCo’s issuance of new shares, our remaining equity holding in CoolCo reduced to 4.5 million shares, or 8.3% as of December 31, 2022. This is a partial disposal of an entity in which we have retained the ability to exercise significant influence and the total gain on disposal of our interest in CoolCo of $0.4 million is included in the consolidated statement of operations line-item “Net income/(losses) from equity method investments”. As of December 31, 2022, CoolCo shares were listed on Euronext at NOK 113.70 $11.60 per share. ECGS In December 2005, we entered into an agreement with the Egyptian Natural Gas Holding Company and HK Petroleum Services to establish a jointly owned company, ECGS, to develop operations in Egypt, particularly in hydrocarbon and LNG related areas. In March 2006, we acquired 0.5 million common shares in ECGS at a subscription price of $1 per share. This represents a 50% interest in the voting rights of ECGS and, in December 2011, ECGS called up its remaining share capital amounting to $7.5 million. Of this, we paid $3.75 million to maintain our 50% equity interest. ECGS does not have quoted market price because the company is not publicly traded. As ECGS is jointly owned and operated, we have adopted the equity method of accounting for our 50% investment in ECGS, as we consider we have joint control. Avenir In October 2018, Golar, Stolt-Nielsen Ltd. (“Stolt-Nielsen”) and Höegh LNG Holdings Limited (“Höegh”) entered into a joint $182.0 million investment in Avenir. Golar contributed $24.8 million in exchange for an initial shareholding of 25% of Avenir. The other shareholders, Höegh and Stolt-Nielsen held initial shareholdings of 25% and 50%, respectively. In November 2018, Avenir announced a private placement of 110 million new shares at a par value price of $1.00 per share. Stolt-Nielsen, Golar and Höegh subscribed for 49.5 million, 24.75 million and 24.75 million shares, respectively. Institutional and other professional investors had subscribed for the remaining 11 million shares. The ownership of Avenir held by Stolt-Nielsen, Golar and Höegh after the placement was diluted to 45%, 22.5% and 22.5%, respectively. As a result, Avenir has been considered as our equity method investment. In March 2020, Avenir issued an equity shortfall notice of $45.0 million which was funded through issuance of additional shares at par value of $1.00 per share. As of December 31, 2022, our $18.0 million commitment to Avenir was fully funded, resulting to a total investment of $42.75 million, representing a 23.5% ownership interest. Aqualung Aqualung is an Oslo-based technology company that has developed and achieved proof of concept for a CO 2 capture and separation membrane technology which could be used to reduce carbon emissions for future FLNG projects. In May 2022, we invested $2.4 million, together with other key strategic partners, DK Innovations (US) Inc., Global Ship Lease Inc., MKS Pamp Group Limited and Standard Lithium Ltd., amounting to a total equity injection of $10 million which resulted in Golar’s 4.4% ownership interest in Aqualung. In August 2022, we were granted representation on the board and accordingly, Aqualung has been considered as an equity method investment. Summarized financial information of our equity method investments shown on a 100% basis are as follows: (in thousands of $) December 31, 2022 CoolCo ECGS Avenir Aqualung Balance Sheet Current assets 145,338 36,504 34,028 5,900 Non-current assets 1,912,723 97 270,177 159 Current liabilities (278,589) (25,501) (69,509) (359) Non-current liabilities (1,063,959) (931) (92,694) — Statement of Operations Revenue 256,434 58,680 62,875 245 Net income/(loss) 110,744 713 (16,217) (2,830) (in thousands of $) December 31, 2021 CoolCo ECGS Avenir Aqualung Balance Sheet Current assets 79,293 41,690 59,741 73 Non-current assets 1,387,215 107 208,949 — Current liabilities (417,453) (31,028) (38,557) (70) Non-current liabilities (306,000) (931) (66,179) — Statement of Operations Revenue 171,919 80,972 16,538 — Net (loss)/income 48,368 55 7,119 (472)

ASSET UNDER DEVELOPMENT

ASSET UNDER DEVELOPMENT	12 Months Ended
ASSET UNDER DEVELOPMENT	Dec. 31, 2022
Extractive Industries [Abstract]
Asset under development	18. ASSET UNDER DEVELOPMENT (in thousands of $) 2022 2021 Opening asset under development balance 877,838 658,247 Additions 221,184 178,377 Interest costs capitalized 53,010 41,214 Closing asset under development balance 1,152,032 877,838 Gimi conversion In February 2019, we entered into an agreement (described further below) relating to a FLNG facility, in connection with the first phase of the Greater Tortue/Ahmeyim Project (the “GTA Project”) situated offshore Mauritania and Senegal, including the conversion of Gimi from a LNGC to a FLNG and her connection with the upstream project infrastructure. In October 2020, we announced that we had confirmed a revised project schedule with BP which extended the target connection date by 11 months to 2023. In June 2022, we agreed a $50 million incentive payment to Keppel to safeguard sail away from the shipyard within first half of 2023. The aggregate conversion cost including financing cost is approximately $1.7 billion of which $700 million is funded by the Gimi facility (note 21). As of December 31, 2022, the estimated timing of the outstanding payments in connection with the Gimi FLNG conversion is as follows: (in thousands of $) Period ending December 31, 2023 385,785 2024 139,669 525,454 Gimi LOA In February 2019, we entered into a Lease and Operate Agreement (which was subsequently amended and restated in September 2021) with BP Mauritania Investments Limited (“BP”), Gimi MS and our subsidiary Golar MS Operator S.A.R.L. (the “LOA”). The LOA provides for the construction and conversion of Gimi to a FLNG, transit, mooring and connection to BP’s project infrastructure, commissioning with BP’s upstream facilities including its floating production, storage and offloading vessel, completing specified acceptance tests, followed by the commencement of commercial operations (“COD”). Following COD, we will operate and maintain FLNG Gimi and make her capacity exclusively available for the liquefaction of natural gas from the GTA Project and offloading of LNG produced for a period of twenty years. Pursuant to the LOA, we and BP are required to meet various delivery schedules. Delays are expected to result in contractual prepayments between the parties in advance of COD. Given the complexity and interdependencies of the activities required during the project mobilization and commissioning leading to COD, it is difficult for us to reasonably estimate eventual net payments/receipts. Post COD, the contractual dayrate is comprised of capital and operating elements. We expect any net payments/receipts in advance of COD to be insignificant in the context of the cash flows we expect to generate over the term of the LOA. BP has two early termination options on specified dates in the event that specified performance metrics are not met, on the occurrence of specified requisition or force majeure events, or upon specified default of our contractual obligations. In addition, BP has a right to purchase FLNG Gimi from the fifteenth anniversary of COD for a purchase price at market value or extend the term of the LOA for delays resulting from specified unforeseen events.

VESSELS AND EQUIPMENT, NET

VESSELS AND EQUIPMENT, NET	12 Months Ended
VESSELS AND EQUIPMENT, NET	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
Vessels and equipment, net	19. VESSELS AND EQUIPMENT, NET (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,264 1,536,736 Additions — — — 77 77 As of December 31 1,374,607 45,771 109,094 7,341 1,536,813 Depreciation, amortization and impairment As of January 1 (223,999) (20,363) (22,767) (5,188) (272,317) Charge for the year (1) (39,449) (5,543) (5,696) (600) (51,288) Impairment (2) (72,607) — (3,548) — (76,155) As of December 31 (336,055) (25,906) (32,011) (5,788) (399,760) Net book value as of December 31, 2022 1,038,552 19,865 77,083 1,553 1,137,053 (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,287 1,536,759 Additions — — — 73 73 Write-offs (3) — — — (96) (96) As of December 31 1,374,607 45,771 109,094 7,264 1,536,736 Depreciation, amortization and impairment As of January 1 (182,474) (14,820) (15,948) (4,267) (217,509) Charge for the year (41,525) (5,543) (6,819) (1,017) (54,904) Write-offs (3) — — — 96 96 As of December 31 (223,999) (20,363) (22,767) (5,188) (272,317) Net book value as of December 31, 2021 1,150,608 25,408 86,327 2,076 1,264,419 (1) Depreciation and amortization charges for the years ended December 31, 2022 and 2021, excludes $0.5 million and, $0.5 million respectively, of amortization charges in relation to the Cameroon license fee. (2) Entry into the Arctic SPA changed the expected recovery of Golar Arctic’s carrying amount from continued use in operations over her remaining useful life, to recovery from sale, and was considered an indicator of impairment. As the revised future estimated cash flows were less than her carrying amount, an impairment charge of $76.2 million was recognized during the year ended December 31, 2022, reflecting an adjustment to her fair value (based on average broker valuation at date of measurement and represents the exit price in the principal LNG carrier sales market). (3) Write-offs relates to fully depreciated or fully amortized assets.

OTHER NON-CURRENT ASSETS

OTHER NON-CURRENT ASSETS	12 Months Ended
OTHER NON-CURRENT ASSETS	Dec. 31, 2022
OTHER NON-CURRENT ASSETS [Abstract]
Other non-current assets	20. OTHER NON-CURRENT ASSETS Other non-current assets is comprised of the following: (in thousands of $) 2022 2021 Gas derivative instrument (note 27) 196,184 — Oil derivative instrument (note 27) 182,795 127,480 MTM asset on IRS derivatives (note 27) 54,970 — MTM asset on TTF linked commodity swap derivatives (note 27) 39,785 — Operating lease right-of-use-assets (1) 5,653 10,293 Others (2) 32,652 3,673 Other non-current assets 512,039 141,446 (1) Operating lease right-of-use-assets mainly comprise of our office leases. (2) Included within “Others” for the year ended December 31, 2022 is expenditure on engineering services and long lead items of $16.7 million and $10.4 million, respectively, for our Mark II FLNG, one of our FLNG design models for prospective conversion of an existing LNG carrier to a FLNG and $2.9 million of engineering and other professional fees in preparation for the conversion of the Golar Arctic pursuant to the terms of Arctic SPA .

DEBT

DEBT	12 Months Ended
DEBT	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt	21. DEBT (in thousands of $) 2022 2021 Total debt, net of deferred finance charges (1,189,324) (1,623,300) Less: Current portion of long-term debt and short-term debt 344,778 703,170 Long-term debt (844,546) (920,130) The outstanding debt, gross of deferred finance charges, as of December 31, 2022 is repayable as follows: Year ending December 31 Golar debt VIE debt (1) Total debt (in thousands of $) 2023 (7,294) (337,666) (344,960) 2024 (43,756) (60,600) (104,356) 2025 (217,363) (60,600) (277,963) 2026 (58,333) (35,500) (93,833) 2027 (58,333) — (58,333) 2028 and thereafter (330,834) — (330,834) Total (715,913) (494,366) (1,210,279) Deferred finance charges 20,699 256 20,955 Total debt net of deferred finance charges (695,214) (494,110) (1,189,324) (1) These amounts relate to a certain lessor entity (for which legal ownership resides with a financial institution) that we are required to consolidate into our financial statements as a VIE (note 5). At December 31, 2022 and 2021, our debt was as follows: (in thousands of $) 2022 2021 Maturity date Gimi facility (535,000) (410,000) March 2030 Unsecured Bonds (159,029) (299,403) October 2025 Golar Arctic facility (21,884) (29,178) October 2024 2017 Convertible bonds — (315,646) Subtotal (excluding lessor VIE debt) (715,913) (1,054,227) CSSC VIE debt - FLNG Hilli facility (494,366) (597,280) Repayable on demand/2026 Total debt (gross) (1,210,279) (1,651,507) Less: Deferred finance charges 20,955 28,207 Total debt, net of deferred financing costs (1,189,324) (1,623,300) Gimi facility In October 2019, we entered into a $700 million facility agreement with a group of lenders to finance the conversion and operations of the Gimi . The facility is available for drawdown during the Gimi conversion and amortizes COD, with a final balloon payment of $350.0 million, due in 2030. The facility bears interest at LIBOR plus a margin of 4.0% during the conversion phase, reducing to LIBOR plus a margin of 3.0% post COD. As of December 31, 2022, we had drawn $535.0 million of the available funds. Subsequent drawdowns are dependent upon reaching further conversion milestones relating to project spend. A commitment fee is chargeable on any undrawn portion of this facility. Unsecured Bonds In October 2021, we closed our $300.0 million senior Unsecured Bonds in the Nordic bond market. The Unsecured Bonds will mature in October 2025 and bear interest at 7.00% per annum. The net proceeds from the Unsecured Bonds was used to partly refinance our $402.5 million 2017 convertible bonds which matured in February 2022 (“Convertible Bonds”) and for general corporate purposes. Contemporaneous with the closing of the Unsecured Bonds, we redeemed $85.2 million of the 2017 convertible bonds and recognized loss on partial redemption of $0.8 million. The terms of the Unsecured Bonds grant us: • an early redemption option to redeem the Unsecured Bonds for 100% of the Nominal Amount if it is required to gross up any withholding tax from any payments in respect of the Unsecured Bonds; • early redemption call option to redeem all of some of the Unsecured Bonds at multiple dates throughout the four year term with pricing that reduces as the maturity date approaches; • to purchase and hold the Unsecured Bonds and that such Unsecured Bonds may be retained, sold or cancelled at our sole discretion; and • grants the bondholders a mandatory repurchase put option to require that that we repurchase some or all of the Unsecured Bonds for 101% of the Nominal Amount per bond – the put option is triggered by a change of control event, a delisting event, a disposal event or a total loss event. In December 2022, we repurchased $140.7 million of the Unsecured Bonds at par for a total consideration of $142.2 million, comprised of premium of $140.7 million and accrued interest up to December 15, 2022 of $1.5 million. A loss on extinguishment of debt of $2.3 million was recognized and presented in “Other financial items, net” in the consolidated statement operations. The repurchase did not result in an amendment to the terms of the remaining outstanding Unsecured Bonds. Golar Arctic facility In October 2019, we entered into an agreement with the existing lenders to extend the maturity of our Golar Arctic facility. The extended facility matures five years from execution, is repayable in quarterly installments and has a final balloon payment of $9.1 million in October 2024. The margin had also increased from 2.25% to 2.75%. 2017 Convertible bonds On February 17, 2017, we closed a $402.5 million aggregate principal amount of 2.75% convertible senior unsecured notes due 2022 (“2017 Convertible Bonds”). In February 2022, we fully redeemed the outstanding notional value of our 2017 Convertible Bonds, inclusive of interest, amounting to $321.7 million. Corporate Revolving Credit Facility In November 2021, we executed a $200.0 million revolving facility (the “Corporate RCF”) which has a term of three years. The Corporate RCF bears interest at LIBOR plus a margin of 2.8% and is secured against our NFE Shares. Under the terms of the Corporate RCF, we are permitted to release a portion of the pledged NFE Shares in accordance with the prescribed loan to value ratio based on the then-current market value of such NFE Shares. In February 2022, we had drawn $131.0 million of the available funds and repaid these funds in May 2022. In November 2022, the Corporate RCF was canceled and the pledge against our remaining NFE shares was released. Corporate bilateral facility In February 2022, we executed a $250 million corporate bilateral facility with Sequoia Investment Management secured by Golar’s ownership in FLNGs Hilli and Gimi . The corporate bilateral facility had a tenor of seven years with a bullet payment maturing in February 2029 and bears interest of LIBOR plus a margin range of 4.5% to 5.5%, subject to certain financial ratio thresholds. In June 2022, the availability of the undrawn corporate bilateral facility expired. Lessor VIE debt The following loan relates to our lessor VIE entity, the CSSC entity that we consolidate as a VIE. Although we have no control over the funding arrangement of this entity, we consider ourselves the primary beneficiary of this VIE and therefore are required to consolidate this loan facility into our financial results (note 5). Facility Effective from SPV Loan counterparty Loan facility at inception (in $ millions) Loan facility at December 31, 2022(in $ millions) Loan duration/maturity Interest Hilli (1) June 2018 Fortune Lianjing Shipping S.A. CSSC entity (840.0) (217.3) 8 years non-recourse LIBOR plus margin (120.0) (277.1) Repayable on demand Nil (1) In July 2019, the SPV, Fortune Lianjiang Shipping S.A., repaid $150.0 million to the interest-bearing facility and subsequently drew down $150.0 million from an internal loan with the CSSC entity. In March, 2020, the SPV, Fortune Lianjiang Shipping S.A., repaid $215.2 million to the interest-bearing facility and subsequently drew down $223.0 million from the internal loan with the CSSC entity. The vessel in the table above is secured as collateral against these long-term loans (note 29). Debt restrictions Certain of our debts are collateralized by vessel liens. The existing financing agreements impose certain operating and financing restrictions which may significantly limit or prohibit, among other things, our ability to incur additional indebtedness, create liens, sell capital shares of subsidiaries, make certain investments, enter into mergers and acquisitions, purchase and sell vessels, enter into time or consecutive voyage charters or distribute dividends. In addition, lenders may accelerate the maturity of indebtedness under financing agreements and foreclose upon the collateral securing the indebtedness upon the occurrence of certain events of default, including a failure to comply with any of the covenants contained in our debt agreements. Many of our debt agreements contain certain covenants, which require compliance with certain financial ratios. Such ratios include current assets: liabilities and minimum net worth and minimum free cash restrictions. With regards to cash restrictions, we have covenanted to retain at least $50.0 million of cash and cash equivalents on a consolidated group basis. As of December 31, 2022, we were in compliance with all our covenants under our various loan agreements.

ACCRUED EXPENSES

ACCRUED EXPENSES	12 Months Ended
ACCRUED EXPENSES	Dec. 31, 2022
Payables and Accruals [Abstract]
Accrued expenses	22. ACCRUED EXPENSES Accrued expenses is comprised of the following: (in thousands of $) 2022 2021 Interest (13,514) (13,767) Vessel related (1) (10,795) (7,925) Administrative related (2) (8,039) (10,122) Current tax payable (485) (1,058) Accrued expenses (32,833) (32,872) (1) “Vessel related” accrued expenses is comprised of vessel operating expenses such as crew wages, vessel supplies, routine repairs, maintenance, drydocking, lubricating oils and insurance. (2) “Administrative related” accrued expenses is comprised of general overhead including personnel costs, legal and professional fees, costs associated with project development, property costs and other general expenses.

OTHER CURRENT LIABILITIES

OTHER CURRENT LIABILITIES	12 Months Ended
OTHER CURRENT LIABILITIES	Dec. 31, 2022
Other Liabilities, Current [Abstract]
Other current liabilities	23. OTHER CURRENT LIABILITIES Other current liabilities is comprised of the following: (in thousands of $) 2022 2021 Day 1 gain deferred revenue - current portion (1) (note 24) (12,783) (38,242) Deferred revenue (6,080) (5,584) Contract liability for other revenue (note 5) (4,177) — Demurrage cost (note 5) (1,608) — Current portion of operating lease liability (note 13) (1,328) (3,006) MTM liability on TTF linked commodity swap derivatives (note 27) — (88) Liability for UK tax leases (note 29) — (71,739) MTM liability on interest rate swaps (note 27) — (17,300) Other payables (2) (1,469) (455) Other current liabilities (27,445) (136,414) (1) Current portion of Day 1 gain deferred on initial recognition of the oil and gas derivative instruments embedded in the LTA (note 7). As of December 31, 2022 and 2021, the Day 1 gain deferred revenue - current portion relating to FLNG Hilli’s oil and gas derivative instruments is $10.0 million and $2.8 million; $10.0 million and $28.3 million, respectively.

OTHER NON-CURRENT LIABILITIES

OTHER NON-CURRENT LIABILITIES	12 Months Ended
OTHER NON-CURRENT LIABILITIES	Dec. 31, 2022
Other Liabilities, Noncurrent [Abstract]
Other non-current liabilities	24. OTHER NON-CURRENT LIABILITIES Other non-current liabilities is comprised of the following: (in thousands of $) 2022 2021 Underutilization liability (note 7) (35,806) — Day 1 gain deferred revenue (1) (31,720) (34,221) Pension obligations (note 25) (24,269) (31,357) Deferred commissioning period revenue (2) (10,396) (14,515) Golar Arctic’s contract liability (3) (7,816) — Non-current portion of operating lease liabilities (note 13) (3,587) (7,136) Other payables (4) (6,834) (5,730) Other non-current liabilities (120,428) (92,959) (1) Non-current portion of Day 1 gain deferred on initial recognition of the oil and gas derivative instruments embedded in the LTA (note 7). As of December 31, 2022 and 2021, the non-current portion of the Day 1 gain deferred revenue relating to FLNG Hilli’s oil and gas derivative instruments is $24.5 million and $7.2 million; $34.2 million and $nil, respectively. (2) FLNG Hilli’s Customer billing during the commissioning period, prior to vessel acceptance and commencement of the LTA, which is considered an upfront payment for services. These amounts billed are recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the Customer’s acceptance of the FLNG Hilli . The current portion of deferred commissioning period billing is included in “Other current liabilities” (note 23). (3) “ Golar Arctic’s contract liability” represents the first advance received from Snam in relation to the Arctic SPA (note 7 and 15). (4) Included in “Other payables” are an asset retirement obligation of $5.7 million and $5.3 million for the years ended December 31, 2022 and 2021, respectively. The corresponding asset of $4.7 million is recorded within vessels and equipment, net (note 19).

PENSIONS

PENSIONS	12 Months Ended
PENSIONS	Dec. 31, 2022
Retirement Benefits [Abstract]
Pensions	25. PENSIONS Defined contribution scheme We operate a defined contribution scheme. The pension cost for the period represents contributions payable by us to the scheme. The charge to net income for the years ended December 31, 2022, 2021 and 2020 was $1.7 million, $2.2 million and $2.1 million, respectively. Defined benefit schemes We have two defined benefit pension plans both of which are closed to new entrants but still cover certain of our employees. Benefits are based on the employees' years of service and compensation. Net periodic pension plan costs are determined using the Projected Unit Credit Cost method. Our plans are funded by us in conformity with the funding requirements of the applicable government regulations. Plan assets consist of both fixed income and equity funds managed by professional fund managers. We use December 31 as the measurement date for our pension plans. The components of net periodic benefit costs are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Service cost (75) (120) (155) Interest cost (1,087) (879) (1,271) Expected return on plan assets 254 214 318 Recognized actuarial loss (774) (1,131) (848) Net periodic benefit cost (1,682) (1,916) (1,956) The components of net periodic benefit costs are recognized in the consolidated statement of operations within " administrative expenses" and "vessel operating expenses" The estimated net loss for the defined benefit pension plans that was amortized from accumulated other comprehensive income into net periodic pension benefit cost during the year ended December 31, 2022 is $0.8 million (2021: $1.1 million). The change in projected benefit obligation and plan assets and reconciliation of funded status for the year ended December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 Reconciliation of benefit obligation: Benefit obligation at January 1 47,215 54,122 Service cost 75 120 Interest cost 1,087 879 Actuarial gain (1) (10,106) (4,081) Foreign currency exchange rate changes (1,227) (120) Benefit payments (2,966) (3,705) Benefit obligation at December 31 34,078 47,215 (1) Actuarial gain is sensitive to changes in key actuarial assumptions specifically discount rates, mortality rates and assumed future salary increases. The accumulated benefit obligation at December 31, 2022 and 2021 was $33.9 million and $46.7 million, respectively. (in thousands of $) 2022 2021 Reconciliation of fair value of plan assets: Fair value of plan assets at January 1 15,858 16,864 Actual return on plan assets (4,392) (46) Employer contributions 2,900 2,900 Foreign currency exchange rate changes (1,591) (155) Benefit payments (2,966) (3,705) Fair value of plan assets at December 31 9,809 15,858 The amounts recognized in accumulated other comprehensive income, as of December 31, 2022 and 2021, is $4.4 million and $10.9 million, respectively. The actuarial loss recognized in other comprehensive income/(loss) is net of tax of $0.3 million, $0.7 million, and $0.6 million for the years ended December 31, 2022, 2021 and 2020, respectively. Employer contributions and benefits paid under the pension plans include $2.9 million paid from employer assets for the years ended December 31, 2022 and 2021. (1) Our defined benefit pension plan is comprised of two schemes as follows: December 31, 2022 December 31, 2021 (in thousands of $) UK Scheme Marine Scheme Total UK Scheme Marine Scheme Total Fair value of benefit obligation (7,073) (27,005) (34,078) (11,608) (35,607) (47,215) Fair value of plan assets 8,801 1,008 9,809 15,077 781 15,858 Funded (unfunded) status at end of year 1,728 (25,997) (24,269) 3,469 (34,826) (31,357) The fair value of our plan assets, by category, as of December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 Equity securities 8,801 15,077 Cash 1,008 781 9,809 15,858 The asset allocation for our Marine scheme at December 31, 2022 and 2021, by asset category are as follows: Marine scheme 2022 (%) 2021 (%) Cash 100 100 Total 100 100 The asset allocation for our UK scheme at December 31, 2022 and 2021, by asset category are as follows: UK scheme 2022 (%) 2021 (%) Equity 100 100 Total 100 100 Our investment strategy is to balance risk and reward through the selection of professional investment managers and investing in pooled funds. We are expected to make the following contributions to the schemes during the year ended December 31, 2023, as follows: (in thousands of $) UK scheme Marine scheme Employer contributions — 2,900 We are expected to make the following pension disbursements as follows: (in thousands of $) UK scheme Marine scheme 2023 340 2,600 2024 370 2,500 2025 470 2,400 2026 390 2,300 2027 400 2,200 2028 - 2032 2,140 9,500 The weighted average assumptions used to determine the benefit obligation for our defined benefit pension plans for the years ended December 31 are as follows: 2022 2021 Discount rate 4.94 % 2.43 % Rate of compensation increase 2.61 % 2.70 % The weighted average assumptions used to determine the net periodic benefit cost for our defined benefit pension plans for the years ended December 31 are as follows: 2022 2021 Discount rate 4.93 % 2.44 % Expected return on plan assets 1.81 % 1.31 % Rate of compensation increase 2.49 % 2.75 % The overall expected long-term rate of return on assets assumption used to determine the net periodic benefit cost for our plans for the years ended December 31, 2022 and 2021 is based on the weighted average of various returns on assets using the asset allocation as of the beginning of 2022 and 2021. For equities and other asset classes, we have applied an equity risk premium over ten-year governmental bonds.

SHARE CAPITAL AND SHARE BASED C

SHARE CAPITAL AND SHARE BASED COMPENSATION	12 Months Ended
SHARE CAPITAL AND SHARE BASED COMPENSATION	Dec. 31, 2021
SHARE CAPITAL AND SHARE OPTIONS [Abstract]
Share capital and share based compensation	26. SHARE CAPITAL AND SHARE BASED COMPENSATION Our common shares are listed on the Nasdaq Stock Exchange. As of December 31, 2022 and 2021, our authorized and issued share capital is as follows: Authorized share capital: (in thousands of $, except per share data) 2022 2021 150,000,000 (2021: 150,000,000) common shares of $1.00 each 150,000 150,000 Issued share capital: (in thousands of $, except per share data) 2022 2021 107,225,832 (2021: 108,222,604) outstanding issued common shares of $1.00 each 107,226 108,223 (number of shares) 2022 2021 As of January 1 108,222,604 109,943,594 Repurchase and cancellation of treasury shares (1) (1,189,653) (1,984,647) Vesting of RSUs 186,881 263,657 Share options exercised 6,000 — As of December 31 107,225,832 108,222,604 (1) During 2022, we repurchased and cancelled 1.2 million treasury shares for a consideration of $25.5 million inclusive of brokers commission of $0.02 million. In 2021, we repurchased and cancelled 2.0 million treasury shares for a consideration of $24.5 million inclusive of brokers commission of $0.04 million. Contributed surplus As of December 31, 2022 and 2021, we have a contributed surplus of $200 million. Contributed surplus is capital that can be returned to stockholders without the need to reduce share capital, thereby giving Golar greater flexibility when it comes to declaring dividends. Share options Our LTIP was adopted by our Board of Directors, effective as of October 24, 2017. The maximum aggregate number of common shares that may be delivered pursuant to any and all awards under the LTIP shall not exceed 3,000,000 common shares, subject to adjustment due to recapitalization or reorganization as provided under the LTIP. The LTIP allows for grants of (i) share options, (ii) share appreciation rights, (iii) restricted share awards (iv) share awards, (v) other share-based awards, (vi) cash awards, (vii) dividend equivalent rights, (viii) substitute awards and (ix) performance-based awards, or any combination of the foregoing as determined by the Board of Directors or nominated committee in its sole discretion. Either authorized unissued shares or treasury shares (if there are any) in the Company may be used to satisfy exercised options. In 2022, there were no share options granted. In 2021, 750,000 share options were awarded to officers. The options vest in equal installments over two years and have a three-year term. The fair value of each option award is estimated on the grant date or modification date using the Black-Scholes option pricing model. The weighted average assumptions as of the May 2021 grant date are noted in the table below: 2021 Risk free interest rate 0.2 % Expected volatility of common stock 85.0 % Expected dividend yield 0.0 % Expected term of options (in years) 2.3 years The assumption for expected future volatility is based primarily on an analysis of historical volatility of our common shares. Where the criteria for using the simplified method are met, we have used this method to estimate the expected term of options based on the vesting period of the award that represents the period options granted are expected to be outstanding. Under the simplified method, the mid-point between the vesting date and the maximum contractual expiration date is used as the expected term. Where the criteria for using the simplified method are not met, we used the contractual term of the options. The dividend yield has been estimated at 0.0% as the exercise price of the options are reduced by the value of dividends, declared and paid on a per share basis. As of December 31, 2022, 2021 and 2020, the number of options outstanding in respect of Golar shares was 1.0 million, 1.5 million and 1.8 million, respectively. A summary of the share options movements during the year ended December 31, 2022 is presented below: Shares Weighted average exercise price Weighted average remaining contractual term Options outstanding at December 31, 2021 1,505 $ 17.65 1.6 Forfeited during the year (334) $ 21.17 Exercised during the year (6) $ 26.90 Lapsed during the year (128) $ 26.44 Options outstanding at December 31, 2022 1,037 $ 15.37 1.0 Options outstanding and exercisable at: December 31, 2022 662 $ 17.87 0.8 December 31, 2021 755 $ 24.28 0.8 December 31, 2020 1,717 $ 24.46 1.2 Options outstanding and exercisable at December 31, 2022 presented above include 73,900 units that were granted to former Golar employees in February 2018 that were acquired by CoolCo as part of the ManCo SPA (note 14.1). The exercise price of all options is reduced by the amount of dividends declared and paid up to 2019. The above figures for options granted, exercised and forfeited show the average of the prices at the time of granting, exercising and forfeiting of the options, and for options outstanding at the beginning and end of the year, the average of the reduced option prices is shown. As of December 31, 2022, the aggregate intrinsic value of share options that were both outstanding and exercisable was $7.7 million. As of December 31, 2021 and 2020, the aggregate intrinsic value of share options that were both outstanding and exercisable was $nil as the exercise price was higher than the market value of the share options at year end. Year ended December 31, (in thousands of $) 2022 2021 2020 Total fair value of share options fully vested in the year 1,958 1,595 3,175 Compensation cost recognized in the consolidated statement of income 1,971 1,434 2,274 Share options cost capitalized* — 16 110 Relates to capitalized costs on share options awarded to employees directly involved in certain vessel conversion projects. As of December 31, 2022, the total unrecognized compensation cost amounting to $0.7 million relating to options outstanding is expected to be recognized over a weighted average period of 0.4 years. Restricted Stock Units (RSU) Time-based RSUs Pursuant to the LTIP, we granted certain individuals 97,215 and nil of RSUs during the years ended December 31, 2022 and 2021, respectively. The RSUs vest equally over a period of 3 years. Refer to ‘Performance-based RSUs’ July 2022 grant discussed below for further details on the RSUs granted in 2022. The fair value of the RSU award is estimated using the market price of our common shares at grant date with the corresponding expense recognized over the three-year vesting period. A summary of time-based RSU activities for the year ended December 31, 2022 is presented below: Shares (in ‘000s) Weighted average grant date fair value per share Weighted average remaining contractual term Non-vested RSUs at December 31, 2021 343 9.71 1.1 Granted during the year 97 22.52 Vested during the year (187) 11.28 Forfeited during the year (35) 9.63 Non-vested RSUs at December 31, 2022 218 14.09 1.2 Non-vested time-based RSUs at December 31, 2022 presented above include 32,249 awards that were granted to former Golar employees in March 2020 that were acquired by CoolCo as part of the ManCo SPA (note 14.1). Performance-based RSUs July 2022 grant In July 2022, pursuant to the LTIP, we granted certain individuals RSUs that are subject to certain market and performance conditions within the performance period from January 1 to December 31, 2022. The market and performance conditions are weighted to determine the maximum number of RSUs that will be awarded. The maximum number of RSUs that may be earned under the award is 138,878. However, 70% of the total award or 97,215 RSUs will vest over the requisite service period of three-years from July 2022 to July 2025 regardless of the achievement of market and performance conditions. These are shown as time-based RSUs in the preceding table and fair value is estimated using the market price of our common shares at grant date. The remaining 30% of the award contingently vests subject to Golar achieving more than 70% of the market and performance conditions. As achievement of certain of the performance conditions are subject to the discretion of the Compensation Committee of our Board of Directors (the “Compensation Committee”), no grant date is established until final approval by the Compensation Committee. As such, fair value is estimated using the market price of our common shares at each period end date until final approval is granted by the Compensation Committee. The market condition was achieved at December 31, 2022, so no fair value adjustment to our share price was necessary. Final approval by the Compensation Committee was granted on January 16, 2023. This award will also vest over the requisite service period of three years from July 2022 to July 2025. March 2020 grant In March 2020, we granted certain individuals RSUs that were subject to the achievement of a total shareholder return (“TSR”) performance condition relative to the TSR of a predetermined group of peer companies over a three-year performance period that ended in December 31, 2022. The maximum number of RSUs that may be earned under the award is 159,430. Payouts of the performance-based RSUs will range from 0% to 100% of the target awards based on our TSR ranking within the peer group. This award will vest in March 2023. The fair value of this award is estimated on the grant date using the Monte Carlo simulation model. The weighted average assumptions as of grant date are noted in the table below: 2020 Remaining performance period 2.8 years Contractual term 3.0 years Expected dividend yield 0.0 % Risk free interest rate 0.42 % Golar volatility 84 % Share price at grant date $ 7.49 The assumption for expected future volatility is based primarily on an analysis of historical volatility of our common shares with an implied volatility factored in for the last 0.9 years of the performance period. A summary of performance-based RSU activity for the year ended December 31, 2022 is presented below: Shares (in ‘000s) Weighted average grant date fair value per share Weighted average remaining contractual term Non-vested performance based RSUs at December 31, 2021 28 6.25 1.2 Granted during the year 42 22.79 Forfeited during the year (1) 22.79 Non-vested performance based RSUs at December 31, 2022 69 16.05 1.6 Year ended December 31, (in thousands of $) 2022 2021 2020 Compensation cost recognized in the consolidated statement of income 1,522 1,774 2,739 RSU cost capitalized 198 322 295 *Relates to capitalized costs on RSUs awarded to employees directly involved in certain vessel conversion projects. Non-vested performance-based RSUs at December 31, 2022 above include 10,520 units that were granted to former Golar employees in March 2020 that were acquired by CoolCo as part of the ManCo SPA (note 14.1). As of December 31, 2022, the total unrecognized compensation cost of $2.6 million relating to both time-based and performance based RSUs outstanding is expected to be recognized over a weighted average period of 2.3 years.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
FINANCIAL INSTRUMENTS	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Financial instruments	27. FINANCIAL INSTRUMENTS Interest rate risk management We may enter into financial instruments to reduce the risk associated with fluctuations in interest rates. We have entered into swaps that convert floating rate interest obligations to fixed rates, which from an economic perspective, hedge the interest rate exposure. The counterparties to such contracts are major banking and financial institutions. Credit risk exists to the extent that the counterparties are unable to perform under the contracts; however we do not anticipate non-performance by any of our counterparties. We do not hold or issue instruments for speculative or trading purposes. We manage our debt portfolio with interest rate swap agreements in U.S. dollars to achieve an overall desired position of fixed and floating interest rates. We ceased hedge accounting for our derivatives in 2015. As of December 31, 2022 and 2021, we were party to the following interest rate swap transactions involving the payment of fixed rates in exchange for LIBOR as summarized below: Instrument Year end Notional value Maturity dates Fixed interest rates Interest rate swaps: Receiving floating, pay fixed 2022 740,000 2024/2029 1.69% to 2.37% Receiving floating, pay fixed 2021 505,000 2024/2029 1.69% to 2.37% Foreign currency risk The majority of our gross earnings are receivable in U.S. dollars. The majority of our transactions, assets and liabilities are denominated in U.S. dollars, our functional currency. However, we incur certain expenditure in other currencies. There is a risk that currency fluctuations will have a negative effect on the value of our cash flows. Commodity price risk management Although the LTA bills at a base rate of $60.00 per barrel over the contract term for 1 million tons of LNG, we bear no downside risk to the movement of oil prices should the oil price move below $60.00. Pursuant to LTA Amendment 3, 0.2 million tons per year of LNG is linked to the TTF index and the Euro/U.S. Dollar foreign exchange movements. We have entered into commodity swaps to economically hedge our exposure to a portion of FLNG Hilli’s tolling fee that is linked to the TTF index, by swapping variable cash receipts that are linked to the TTF index for anticipated future production volumes with fixed payments from our TTF swap counterparties. We have entered into master netting agreements with our counterparties and are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade institutions. Instrument Year end Notional quantity (MMBtu) Maturity date Fixed price/MMBtu Commodity swap derivatives: Receiving fixed, pay floating 2022 4,839,000 2023 - 2024 $49.50 to $51.20 Receiving fixed, pay floating 2021 1,209,753 2023 - 2024 $23.25 to $28.00 Equity price risk Our Board of Directors previously approved a share repurchase program, which was partly financed through the use of total return swap or equity swap facilities with third party banks, indexed to our own shares. We carry the risk of fluctuations in the share price of those acquired shares. The banks were compensated at their cost of funding plus a margin. In February 2020, we purchased the remaining 1.5 million of our shares and 107,000 of Golar Partners’ common units underlying the total return swap, at an average price of $46.91 and $21.40, respectively at a fair consideration of $72.7 million, of which $59.3 million represented restricted cash that was released on the repurchase, with $55.5 million to settle the derivative liability fair value and $17.2 million relating to the fair value of the shares and units underlying the total return swap. The effect of our total return swap facilities in our consolidated statement of operation as of December 31, 2020 was a loss of $5.1 million. Fair values of financial instruments We recognize our fair value estimates using a fair value hierarchy based on the inputs used to measure fair value. The fair value hierarchy has three levels based on reliability of inputs used to determine fair value as follows: Level 1: Quoted market prices in active markets for identical assets and liabilities. Level 2: Observable market based inputs or unobservable inputs that are corroborated by market data. Level 3: Unobservable inputs that are not corroborated by market data. The carrying values and estimated fair values of our financial instruments at December 31, 2022 and 2021 are as follows: 2022 2022 2021 2021 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents (1) Level 1 878,838 878,838 231,849 231,849 Restricted cash and short-term deposits (2) Level 1 134,043 134,043 106,073 106,073 Trade accounts receivable (2) Level 1 41,545 41,545 28,912 28,912 Receivable from TTF linked commodity swap derivatives (2) Level 1 4,638 4,638 — — Receivable from IRS derivatives (2) Level 1 1,923 1,923 — — Investment in listed equity securities (3) Level 1 224,788 224,788 449,666 449,666 TTF linked commodity swap collateral (2) (note 16) Level 1 — — 6,940 6,940 Trade accounts payable (3) Level 1 (8,983) (8,983) (4,929) (4,929) Assets held for sale (note 14) Level 2 721 721 1,697,776 1,697,776 Liabilities held for sale (note 14) Level 2 (373) (373) (879,904) (879,904) Current portion of long-term debt and short-term debt (2) (4) (5) Level 2 (344,960) (344,960) (388,005) (388,005) Current portion of 2017 Convertible Bonds (4) (6) Level 2 — — (315,646) (316,561) Long-term debt (6) (7) Level 2 (706,290) (706,290) (947,855) (947,855) Long-term debt - Unsecured Bonds (4) (6) Level 1 (159,029) (158,092) — — Derivatives: Oil and gas derivative instruments (7) Level 2 378,979 378,979 207,058 207,058 Asset on IRS derivatives (8) Level 2 54,970 54,970 — — Liability on IRS derivatives (8) Level 2 — — (17,300) (17,300) Asset on TTF linked commodity swap derivatives (8) (9) Level 2 113,368 113,368 1,753 1,753 Liability on TTF linked commodity swap derivatives (8) (9) Level 2 — — (88) (88) (1) These instruments carrying value is highly liquid and is a reasonable estimate of fair value. (2) These instruments are considered to be equal to their estimated fair value because of their near term maturity. (3) “Investment in listed equity securities” refers to our NFE Shares (note 16). The fair value is based on the NFE closing share price as of the balance sheet date. (4) Our debt obligations are recorded at amortized cost in the consolidated balance sheets. The amounts presented in the table are gross of the deferred charges amounting to $21.0 million and $28.2 million at December 31, 2022 and 2021, respectively. (5) The estimated fair values for both the floating long-term debt and short-term debt are considered to be equal to the carrying value since they bear variable interest rates, which are adjusted on a quarterly or six-monthly basis. (6) The estimated fair values of our unsecured 2017 Convertible Bonds and Unsecured Bonds are based on their quoted market prices as of the balance sheet date. In February 2022, following the listing of the Unsecured Bonds, the fair value hierarchy transferred from Level 2 to Level 1. (7) The fair value of the oil and gas derivative instruments is determined using the estimated discounted cash flows of the additional payments due to us as a result of oil and gas prices moving above the contractual floor price over the remaining term of the LTA. Significant inputs used in the valuation of the oil and gas derivative instruments include the Euro/U.S. Dollar exchange rates based on the forex forward curve for the gas derivative instrument and management’s estimate of an appropriate discount rate and the length of time necessary to blend the long-term and short-term oil and gas prices obtained from quoted prices in active markets. (8) 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. The credit exposure of certain derivative instruments is represented by the fair value of contracts with a positive value at the end of each period, reduced by the effects of master netting arrangements. (9) Does not include collateral posted with counterparties to our TTF commodity swaps. We have recognized cash collateral receivable of $nil and $6.9 million as of December 31, 2022 and 2021, respectively, in relation to our TTF commodity swaps (note 16). The following methods and assumptions were used to estimate the fair value of our other classes of financial instruments: • The carrying values of loan receivables and working capital facilities approximate fair values because of the near-term maturity of these instruments (note 16, 23 and 28). These instruments are classified within Level 1 of the fair value hierarchy. • Our pension plan assets are primarily invested in funds holding equity and debt securities, which are valued at quoted market price (note 25). These plan assets are classified within Level 1 of the fair value hierarchy. The following table summarizes the fair value of our derivative instruments on a gross basis (none of which have been designated as hedges) recorded in our consolidated balance sheets as of December 31, 2022 and 2021 : Balance sheet classification 2022 2021 (in thousands of $) Asset derivatives Gas derivative instrument Other current assets and other non-current assets (note 16 and note 20) 196,184 79,578 Oil derivative instrument Other non-current assets (note 20) 182,795 127,480 Commodity swaps Other current assets and other non-current assets (note 16 and note 20) 113,368 1,753 Interest rate swaps Other non-current assets (note 20) 54,970 — Total asset derivatives 547,317 208,811 Liability derivatives Interest rate swaps Other current liabilities (note 23) — (17,300) Commodity swap Other current liabilities (note 23) — (88) Total liability derivatives — (17,388) The amounts presented in our consolidated balance sheet in relation to interest rate and commodity swaps have not been offset. For our commodity swaps, if we were to offset and record the asset and liability balances of derivatives on a net basis, the amounts presented in our consolidated balance sheets as of December 31, 2022 and 2021 would be adjusted as in the following table: 2022 2021 Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount (in thousands of $) Commodity swaps Total asset derivatives 113,368 — 113,368 1,753 (88) 1,665 Total derivative liabilities — — — (88) 88 — Concentrations of risk There is a concentration of credit risk with respect to cash and cash equivalents and restricted cash to the extent that substantially all of the amounts are carried with Nordea Bank ABP, DNB Bank ASA, Citibank NA, SCB, ABN Amro Bank NV, Internationale Nederlanden Groep Bank and Danske Bank A/S. However, we believe this risk is remote, as they are established and reputable financial institutions with no prior history of default and with investment grade credit ratings. Included within cash and cash equivalents of $878.8 million and $231.8 million are $634.2 million and $nil held in short-term money market deposits which had earned interest income of $7.6 million and $nil during the years ended December 31, 2022 and 2021, respectively. There is a concentration of financing risk with respect to our long-term debt to the extent that a substantial amount of our long-term debt is carried with ABN Amro Bank NV, as well as with the CSSC entity in regards to our sale and leaseback arrangement on the FLNG Hilli (note 5). We believe these counterparties to be sound financial institutions, with investment grade credit ratings. Therefore, we believe this risk of default is remote. We also have equity method investments in CoolCo and Avenir, as of December 31, 2022, with carrying values recorded in our balance sheet of $55.4 million and $41.8 million, respectively. Accordingly, the value of our investments and our share of the net results generated from Avenir and CoolCo are subject to specific risks associated with their business. In the event the fair value of the investments falls below the carrying values and they are determined to be other-than-temporary, we would be required to recognize an impairment loss. A concentration of supplier risk exists in relation to the Gimi undergoing FLNG conversion with Keppel and B&V. However, we believe this risk is remote as Keppel is a global leader in the shipbuilding and vessel conversion sectors while B&V is a global engineering, procurement and construction company. A further concentration of supplier risk exists in relation to the Mark II FLNG project conversion for long lead items with Nuovo Pignone International S.R.L, Kanfa AS, Chart Energy, Chemicals Inc, Siemens Energy AG and Howden Turbo UK Ltd. However, we believe this risk is remote as they are all global reputable procurement companies.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
RELATED PARTY TRANSACTIONS	Dec. 31, 2022
Related Party Transactions [Abstract]
Related party transactions	28. RELATED PARTY TRANSACTIONS a) Transactions with CoolCo: As further described in note 14, on June 30, 2022, we completed the CoolCo Disposals and had entered into the following transactions: Net revenues: The transactions with CoolCo during the year ended December 31, 2022 consists of the following: (in thousands of $) 2022 Management and administrative services revenue (1) 3,124 Ship management fees revenue (2) 1,249 Ship management fees expense (3) (5,811) Debt guarantee fees (4) 837 Commitment fee (5) 115 Total (486) (1) Management and administrative services revenue – Golar Management Limited (“Golar Management”), a wholly-owned subsidiary of Golar, and Golar Management (Bermuda) Ltd, entered into the CoolCo TSA (subsequently replaced with the CoolCo ASA), both described further in note 14.1, pursuant to which we provided corporate administrative services to CoolCo. The CoolCo ASA expires on June 30, 2023. (2) Ship management fee revenue – We provided commercial and technical management to the LNG carriers prior to disposal to CoolCo under the existing management agreements, however the CoolCo TSA revised the annual management fee payable to us per vessel. On June 30, 2022, upon completion of the CoolCo Disposal, the ship management agreements were terminated. (3) Ship management fee expense – Following completion of the ManCo SPA with CoolCo in June 2022, we entered into ship management agreements with CoolCo, to provide commercial and technical management for certain of our LNG carriers, amounting to (i) $0.6 million ship management fees for the Golar Arctic and Golar Tundra and (ii) $0.1 million fees incurred for FLNG crewing for the year ended December 31, 2022. We also entered into an agreement to sub-contract our contractual vessel management obligations for the LNG Croatia and NFE’s fleet of vessels to CoolCo amounting to $5.1 million for the for the year ended December 31, 2022. The ship management fee revenue of $4.8 million received in relation to NFE’s fleet of vessels is passed on at cost to CoolCo as our subcontracting ship management expenses presented on “Administrative expenses” in the consolidated statements of operations. (4) Debt guarantee fees – We agreed to remain as the guarantor of the payment sale and lease-back obligations of two of the disposed subsidiaries, which are the disponent owners of the Golar Ice and the Golar Kelvi n, in exchange for a guarantee fee of 0.5% on the outstanding principal balances, which as of December 31, 2022 is $210.3 million. The compensation amounted to $0.8 million for the year ended December 31, 2022. (5) Commitment fee – We advanced a two years revolving credit facility of $25.0 million to CoolCo, which remains undrawn as of December 31, 2022. The facility bears a fixed interest rate and commitment fee on the undrawn loan of 5% and 0.5% per annum, respectively. The commitment fee amounted to $0.1 million for the year ended December 31, 2022. Receivables: The balances with CoolCo and its subsidiaries as of December 31, 2022 consisted of the following: (in thousands of $) 2022 Balance due from CoolCo and subsidiaries (6) 394 (6) Balances due from CoolCo and its subsidiaries - Amounts due to/from CoolCo and its subsidiaries are comprised primarily of unpaid management servic es, amounts arising from the results of CoolCo ’ s vessels participating in the Cool Pool, revolving credit facility, commitment fees and other related arrangements. Payables and receivables are generally settled quarterly in arrears. Balances owing to or due from CoolCo and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. Other transactions: Net Cool Pool expenses - The eight TFDE vessels sold in the CoolCo Disposal were previously managed by Golar under the terms of the Cool Pool. The net expenses relating to the CoolCo’s vessels participation in the pool amounted to $4.8 million for the year ended December 31, 2022. This is presented in our consolidated statement of operations in the line item “Net (loss)/income from discontinued operations”. Subleases with CoolCo - Following the completion of the CoolCo Disposal, we entered into subleases to share office space with CoolCo which amounted to $0.4 million income (note 13). Share-based payment to CoolCo employees - Following the completion of the ManCo SPA, we agreed to honor the RSUs granted to the officers and employees in the shipping and FSRU management business that CoolCo acquired. The net expenses relating to these share-based payments amounted to $0.1 million for the year ended December 31, 2022 is included in our equity method investment in CoolCo. Reimbursements to CoolCo - Payments on behalf of CoolCo amounted to $0.1 million for the year ended December 31, 2022 . b) Transactions with existing related parties: Net revenues/(expenses): The transactions with other related parties for the years ended December 31, 2022, 2021 and 2020 consisted of the following: (in thousands of $) 2022 2021 2020 Avenir (1) 246 468 980 Magni Partners (2) (32) (189) (606) ECGS (3) — 1,482 — Total 214 1,761 374 Receivables: The balances with other related parties as of December 31, 2022 and 2021 consisted of the following: (in thousands of $) 2022 2021 Avenir (1) 3,472 3,225 Magni Partners (2) 81 81 Total 3,553 3,306 (1) Avenir entered into agreements to compensate Golar in relation to the provision of certain debt guarantees relating to Avenir and its subsidiaries. This compensation amounted to $0.1 million, $0.5 million and $1.0 million for the years ended December 31, 2022, 2021 and 2020, respectively. In October 2021, we advanced a one year revolving shareholder loan of $5.3 million to Avenir, of which $1.8 million was drawn as of December 31, 2022. In October 2022, the revolving shareholder loan was extended to three years. The facility bears a fixed interest rate of 5% per annum. The aggregated interest and commitment fee receivable on the undrawn portion of the loan amounted to $143 thousand and $28 thousand, for the years ended December 31, 2022 and 2021, respectively. (2) Magni Partners - Tor Olav Trøim is the founder of, and partner in, Magni Partners (Bermuda) Limited (“Magni Partners”), a privately held Bermuda company, and is the ultimate beneficial owner of the company. Receivables and payables from Magni Partners comprise primarily of the cost (without mark-up) or part cost of personnel employed by Magni Partners who have provided advisory and management services to Golar. These costs do not include any payment for any services provided by Tor Olav Trøim himself. (3) We chartered our former LNG carrier, the Golar Ice to ECGS during the year ended December 31, 2021. There was no comparable transaction for the year ended December 31, 2022. c) Transactions with former related parties Net revenues: The following tables represents the transactions before these companies ceased to be our related parties for the years ended December 31, 2021 and 2020: (in thousands of $) 2021 2020 Transactions Golar Partners and subsidiaries 3,986 13,521 Hygo and subsidiaries 3,631 10,887 Borr Drilling 348 384 2020 Bulkers 111 45 OneLNG 64 — Total 8,140 24,837 Receivables: The balances before these companies ceased to be our related parties as of December 31, 2021 consisted the following: (in thousands of $) 2021 Balances Borr Drilling 149 2020 Bulkers 29 Total 178 c.1) Golar Partners and subsidiaries: Following the completion of the GMLP Merger on April 15, 2021, Golar Partners was no longer considered a related party and subsequent transactions with Golar Partners and its subsidiaries are treated as a third party and settled under normal payment terms. For the balances with Golar Partners and its subsidiaries prior to the completion of the GMLP Merger, we retrospectively adjusted the comparative period and classified them as held for sale. Furthermore, the management and administrative services agreement and ship management fee agreement were terminated and replaced with the transition services agreement, Bermuda services agreement and ship management agreements (note 14). The following table represent the transactions with Golar Partners and its subsidiaries for the period from January 1, 2021 to April 15, 2021 and for the year ended December 31, 2020: (in thousands of $) Period January 1, 2021 to April 15, 2021 Year Ended December 31, 2020 Management and administrative services revenue 1,717 7,941 Ship management fees revenue 2,251 5,263 Interest income on short-term loan 18 317 Total 3,986 13,521 Other transactions: During the period from January 1, 2021 to April 15, 2021 and year ended December 31, 2020, we received total distributions from Golar Partners of $0.5 million and $10.5 million, respectively, with respect to common units and general partners units owned by us at that time. During the period from January 1, 2021 to April 15, 2021 and year ended December 31, 2020, Hilli LLC declared distributions totaling $7.2 million and $19.4 million, respectively, with respect to the common units owned by Golar Partners. In connection with the Hilli Disposal, we agreed to indemnify Golar Partners for certain costs incurred in FLNG Hilli operations when these costs exceed a contractual ceiling, capped at $20 million. Costs indemnified include vessel operating expenses, taxes, maintenance expenses, employee compensation and benefits, and capital expenditures. Included within the FLNG Hilli distributions for the period from January 1, 2021 to April 15, 2021 and year ended December 31, 2020, is $0.1 million and $0.4 million, respectively with respect to FLNG Hilli’s indemnification cost. c.2) Hygo and subsidiaries: Following the completion of the Hygo Merger on April 15, 2021, Hygo ceased to be a related party and subsequent transactions with Hygo and its subsidiaries are treated as third-party transactions and settled under normal payment terms. For the balances with Hygo and its subsidiaries prior to the completion of the Hygo Merger, we retrospectively adjusted the comparative period and classified them as held for sale. Furthermore, the management and administrative services agreement and ship management fee agreement were terminated and replaced with the transition services agreement, Bermuda services agreement and ship management agreements (note 14). The following table represent the transactions with Hygo and its subsidiaries for the period from January 1, 2021 to April 15, 2021 and for the year ended December 31, 2020: (in thousands of $) Period January 1, 2021 to April 15, 2021 Year Ended December 31, 2020 Management and administrative services revenue 2,051 5,281 Ship management fees income 904 1,780 Debt guarantee compensation 676 3,826 Total 3,631 10,887 Other transactions: Net Cool Pool expenses - Net expenses relating to the other pool participants are presented in our consolidated statement of operation in the line item “Voyage, charterhire and commission expenses” for the period from January 1, 2021 to April 15, 2021 and for the year ended December 31, 2020 amounted to $2.9 million and $2.1 million, respectively. c.3) Borr Drilling: Tor Olav Trøim is the founder and director of Borr Drilling Limited (“Borr Drilling”), a Bermuda company listed on the Oslo and Nasdaq stock exchanges. Transactions with Borr Drilling include management and administrative services provided by our Bermuda corporate office. Effective from January 2022, Borr Drilling ceased to be a related party. c.4) 2020 Bulkers: Transactions with 2020 Bulkers Ltd. (“2020 Bulkers”) include management and administrative services provided by our Bermuda corporate office. Effective from January 2022, 2020 Bulkers ceased to be a related party. c.5) OneLNG and subsidiaries:

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
COMMITMENTS AND CONTINGENCIES	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and contingencies	29. COMMITMENTS AND CONTINGENCIES Assets pledged Year ended December 31, (in thousands of $) 2022 2021 Book value of vessels secured against long-term loans (1) 1,115,500 1,242,343 (1) This excludes the Gimi which is classified as “Assets under development” (note 18) and secured against the Gimi debt facility (note 21). Corporate RCF The Corporate RCF was secured by a pledge against our NFE Shares. We were permitted under the terms of the facility, to release a portion of the pledged NFE Shares in accordance with the prescribed loan to value ratio based on the then-current market value of such NFE Shares. In November 2022, the Corporate RCF was canceled and the pledge against our NFE shares was released. Capital Commitments Mark II FLNG In 2022, our Board of Directors had approved up to $328.5 million of capital expenditures for a Mark II FLNG. As of December 31, 2022, we entered into agreements for engineering services and long lead items amounting to $199.2 million (note 20). Tundra Development Agreement As of December 31, 2022, we have committed $12.9 million of yard cost and materials in relation to the drydocking, site commissioning and hook-up services of the Golar Tundra (note 7). Arctic SPA As of December 31, 2022, we have committed $4.8 million of engineering and other professional costs in relation to the FSRU conversion of the Golar Arctic (note 7). Gandria We have agreed contract terms for the conversion of the Gandria to a FLNG. The Gandria is currently in lay-up awaiting delivery to Keppel for conversion. The conversion agreement is subject to certain payments and lodging of a full notice to proceed. We have also provided a guarantee to cover the sub-contractor’s obligations in connection with the conversion of the vessel. Other contingencies UK tax lease benefits During 2003 we entered into six UK tax leases. Under the terms of the leasing arrangements, the benefits are derived primarily from the tax depreciation assumed to be available to the lessors as a result of their investment in the vessels. As is typical in these leasing arrangements, as the lessee we are obligated to maintain the lessor’s after-tax margin. The UK tax authority (“HMRC”) challenged the use of similar lease structures and had engaged in litigation of a test case. In 2021, we reached a settlement with HMRC and in April 2022, we settled our liability to HMRC in full, resulting in a payment of $66.4 million, inclusive of fees, of which $16.0 million was released from restricted cash earmarked for such settlement (note 15). 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 contingent liability 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. For each of the years ended December 31, 2022, 2021 and 2020 we received LOH insurance income for Golar Ice of $4.4 million , $nil and $nil, respectively. The above is recognized in “Other operating income/(losses)” in our consolidated statement of operations .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
SUBSEQUENT EVENTS	Dec. 31, 2022
Subsequent Events [Abstract]
Subsequent events	30. SUBSEQUENT EVENTS Financing Dutch Title Transfer Facility (“TTF”) linked commodity swap derivatives In January 2023, we entered into new commodity swaps to effectively unwind the majority of our previous 2023 and 2024 TTF linked commodity swap arrangements and regain full market exposures of the TTF prices, as follows: • 100% of the March 2023 to December 2023 TTF linked commodity swaps unwound at $21.80/MMBtu resulting in a net gain of $28.20/MMBtu, equivalent to $75.8 million that will be received in monthly installments between March and December 2023; and • 50% of January 2024 to December 2024 TTF linked commodity swaps Divestment of our NFE investment In January and February 2023, we sold 1.2 million of our NFE common shares raising net proceeds of $45.6 million. In February 2023, we agreed to acquire NFE’s Hilli Common Units of Hilli LLC (which represents 50% of the Hilli Common Units outstanding), disponent owner of FLNG Hilli , in exchange for our remaining 4.1 million NFE common shares and $100.0 million cash. Ownership and title to the Hilli Common Units transferred to us on the closing date of March 15, 2023, however we acquired the distributions rights from the repurchased Hilli Common Units with retrospective effect from January 1, 2023. Upon the closing of the acquisition, our effective interest in the currently contracted FLNG Hilli earnings is as follows: • 94.6% of Hilli Common Units that receive the base tolling fees, and 5% of gas linked tolling fees; • 89.1% of Series A Special Units that receive the oil linked tolling fees; and • 89.1% of Series B Special Units that receive 95% of gas linked tolling fees. Sale of our CoolCo shares In February 2023, we sold 4.5 million of our CoolCo shares at NOK 130/share, raising net proceeds of $55.8 million. FLNG business development Mark II FLNG In February 2023, we secured an option to acquire a 148,000 cbm moss design LNG carrier for a Mark II FLNG conversion. A non-refundable payment of $5.0 million was paid in February 2023, which, subject to the option being exercised in Q2 2023, will be deducted from the agreed $78.0 million purchase price. Significant progress has been made with the conversion shipyard, procurement of long lead items and financing. Hilli LTA Amendment 4 In 2023, we have agreed in principle LTA Amendment 4 with our Customer, to compensate the contract year 2022 underutilization of $35.8 million through overproduction in contract year 2023.

BASIS OF PREPARATION AND SIGN_2

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Basis of presentation	Basis of preparationThese consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”).
Principles of consolidation	Principles of consolidation A variable interest entity (“VIE”) is defined by the accounting standard as a legal entity where either (a) equity interest holders as a group lack the characteristics of a controlling financial interest, including decision-making ability and an interest in the entity’s residual risks and rewards, (b) equity interest holders have not provided sufficient equity investment to permit the entity to finance its activities without additional subordinated financial support, or (c) the voting rights of some investors are not proportional to their obligations to absorb the expected losses of the entity, their rights to receive the expected residual returns of the entity, or both and substantially all of the entity’s activities either involve or are conducted on behalf of an investor that has disproportionately few voting rights. A party that is a variable interest holder is required to consolidate a VIE if the holder has both (a) the power to direct the activities that most significantly impact the entity’s economic performance and (b) the obligation to absorb losses that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The accompanying consolidated financial statements include the financial statements of the entities listed in notes 4 and 5. Investments in entities in which we directly or indirectly hold more than 50% of the voting control are consolidated in the financial statements, as well as VIEs in which the Company is deemed to be subject to a majority of the risk of loss from the VIE’s activities or entitled to receive a majority of the VIE’s residual returns, or both. All inter-company balances and transactions are eliminated. The non-controlling interests of the above-mentioned subsidiaries were included in the consolidated balance sheets and statements of operations as “Non-controlling interests”. Changes in our ownership interest while we retain a controlling financial interest in a subsidiary are accounted for as equity transactions. The carrying amount of the non-controlling interest is adjusted to reflect our changed ownership interest, with any difference between the fair value of consideration and the amount of the adjusted non-controlling interest being recognized in equity. We recognize a gain or loss when a subsidiary issues its stock to third parties at a price per share in excess or below its carrying value resulting in a reduction in our ownership interest in the subsidiary. The gain or loss is recorded in the line “Additional paid-in capital” within the statement of changes in equity. When a consolidated subsidiary issues preferred stock, such preferred stock is classified as equity. Preferred stock issued by a consolidated subsidiary to non-controlling interests is recorded as non-controlling interests for the proceeds received upon issuance.
Foreign currencies	Foreign currencies Our functional currency is the U.S. dollar as most of our revenues are received in U.S. dollars and a majority of our expenditures are incurred in U.S. dollars. Our reporting currency is U.S. dollars. Transactions in foreign currencies during the year are translated into U.S. dollars at the exchange rates in effect at the date of the transaction. Monetary assets and liabilities are translated using exchange rates at the balance sheet date. Non-monetary assets and liabilities are translated using historical exchange rates. Foreign currency transaction and translation gains or losses are included in the consolidated balance sheets and consolidated statements of operations.
Use of estimates	Use of estimates The preparation of financial statements requires management to make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of material 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. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual values, charter rates, vessel operating expenses and drydocking requirements. In relation to the oil derivative instrument (note 27), fair value is 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 FLNG Hilli’s Liquefaction Tolling Agreement (“LTA”). The fair value of the gas derivative is determined using the estimated discounted cash flows of the additional payments due to us as a result of forecasted natural gas prices and forecasted Euro/U.S. Dollar exchange rates. Significant inputs used in the valuation of the oil and gas derivative instruments include an appropriate discount rate and the length of time necessary to blend the long-term and short-term oil and gas prices obtained from quoted prices in active markets. The changes in fair value of our oil and gas derivative instruments are recognized in each period within “Realized and unrealized gains/(loss) on oil and gas derivative instruments” in the consolidated statement of operations (note 8).
Fair value measurements	Fair value measurements We account for fair value measurements in accordance with ASC 820 Fair value measurement to measure assets and liabilities. The guidance provides a definition of fair value, together with a framework for measurement and requires additional disclosure about the use of fair value to measure assets and liabilities.
Lease versus revenue accounting	Lease versus revenue accounting Contracts relating to our LNG carrier, FSRU and FLNG assets can take various forms including leases, tolling services and management service agreements. In addition, we have historically contracted a portion of our vessels in the spot market through the “Cool Pool” arrangement. Although the substance of these contracts is similar (they allow our counterparties to hire a managed vessel for specified consideration), the accounting treatment varies. To determine whether a contract contains a lease agreement for a period of time, the Company assesses whether, throughout the period of use, the counterparty has both of the following: • the right to obtain substantially all of the economic benefits from the use of the identified asset; and • the right to direct the use of that identified asset. If a contract relating to an asset fails to give both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e., another third party could contract for a meaningful amount of the asset capacity). In situations where we have historically provided management services unrelated to an asset contract, we account for the contract as a revenue contract. Lease accounting When a contract contains a lease, which is assessed at inception, we make an assessment of the lease classification criteria of ASC 842 Leases . An agreement will be classified as a sales-type lease for a lessor (or a finance lease for a lessee) if any of the following conditions are met at lease commencement: • ownership of the asset is transferred at the end of the lease term; • the contract contains an option to purchase the asset which is reasonably certain to be exercised; • the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the underlying asset’s useful life are not subject to this criterion; • the present value of the lease payments and any residual value guarantees present represent substantially all of the fair value of the underlying asset; and • the asset is heavily customized such that it could not be used for another use at the end of the term. If none of these criteria are met for a lessor, the lease will be classified as a direct financing lease (if the present value of the sum of the lease payments and any residual value guarantee present equals or exceeds substantially all of the fair value of the underlying asset and it is probable that the lessor will collect lease payments and any residual value guarantee), or an operating lease. If none of these criteria are met for a lessee, the lease will be classified as an operating lease.
Lessor accounting	Lessor accounting In making the classification assessment, we have historically estimated the residual value of the underlying asset at the end of the lease term with reference to broker valuations. Generally, lease accounting commences when the asset is made available to the counterparty, however, where a contract contains specific acceptance testing conditions, lease accounting will not commence until the asset has successfully passed the acceptance tests. We assess a lease under the modification guidance when there is a change to the terms and conditions of the contract that results in a change in the scope or the consideration of the lease. For operating leases, costs directly associated with the execution of the lease or costs incurred after lease inception (the execution of the contract) but prior to the commencement of the lease that directly relates to preparing the asset for the contract (for example bunker costs), are capitalized and amortized to the consolidated statement of income over the lease term. We also defer upfront net revenue payments (for example positioning fees) for operating leases to the consolidated balance sheet and amortize to the consolidated statement of income over the lease term. Fixed revenue from operating leases is accounted for on a straight-line basis over the life of the lease; while variable revenue is accounted for as incurred in the relevant period. Fixed revenue includes fixed payments and variable payments based on a rate or index. For our operating leases for LNG carriers, we have historically elected the practical expedient to combine our service revenue and operating lease income generated from our time charter agreements as both the timing and the pattern of transfer of the components are the same. • Time charter agreements Revenues include minimum lease payments under time charters, fees for positioning and repositioning vessels, and gross pool revenues. Revenues generated from time charters, which we generally classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage. Initial direct costs (those directly related to the negotiation and consummation of the lease) are deferred and allocated to earnings over the lease term. Rental income and expense are amortized over the lease term on a straight-line basis. Repositioning fees (included in time and voyage charter revenues) received in respect of time charters are recognized at the end of the charter when the fee becomes fixed and determinable. However, where there is a fixed amount specified in the charter, which is not dependent upon redelivery location, the fee will be recognized evenly over the term of the charter. Under time charters, voyage expenses are generally paid by our customers. Voyage related expenses, principally fuel, may also be incurred when positioning or repositioning the vessel before or after the period of time charter and during periods when the vessel is not under charter or is off-hire, for example when the vessel is undergoing repairs. These expenses are recognized as incurred.
Revenue and related expense recognition	Revenue accounting Contracts within the scope of revenue accounting are generally those that do not contain a lease or that form part of our ordinary activities of developing and operating FLNG projects. Contracts with a customer are assessed to identify the performance obligations in the contract, determine the transaction price and allocation of the transaction price to the performance obligations identified. Revenue is recognized when the performance obligations are satisfied – either over time or at a point in time and the appropriate pattern of transfer of control over time. Contract liabilities arise when the customer makes payments in advance of receiving services while contract assets arise when services are provided in advance of customer payments being received. • Liquefaction services revenue For liquefaction services revenue, the provision of liquefaction services capacity is considered a single performance obligation recognized evenly over time. We consider our services (the receipt of customer’s gas, treatment and temporary storage on board our FLNG and delivery of LNG to waiting carriers) to be a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. We recognize revenue when obligations under the terms of our contract are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice. Amounts of overproduction or underutilization is variable consideration, estimated and recognized using the output method to the extent it is probable that a significant reversal will not occur. Contractual payment terms for liquefaction services is monthly in arrears. The period between when invoicing and when payment is due is not significant. • Services revenue Services revenue is generated from services rendered which includes but not limited to performing drydocking, site commissioning, hook-up services, FLNG studies and other services. • Management fees Management fees are generated from vessel management, which includes commercial and technical vessel-related services, ship operations and maintenance services and administrative services. The management services we provide are considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services as a series of distinct services that are substantially the same and have the same pattern of transfer to the customer. We recognize revenue when obligations under the terms of our contracts with our customers are satisfied. We have applied the practical expedient to recognize management fee revenue in proportion to the amount that we have the right to invoice. Our contracts generally have an initial term of one year or less, after which the arrangement continues until the end of the contract. • Cool Pool Pool revenues and expenses under the Cool Pool arrangement are accounted for in accordance with the guidance for collaborative arrangements when two (or more) parties are active participants in the activity and are exposed to significant risks and rewards dependent on the commercial success of the activity. Active participation is deemed to occur when participating on the Cool Pool steering committee. When accounting for a collaborative arrangement, we present our share of net income earned under the Cool Pool across a number of lines in the consolidated statement of operations. Net revenue and expenses incurred specifically to Golar vessels and for which we are deemed to be the principal, are presented gross on the face of the consolidated statement of operations in the line items “Time and voyage charter revenues” and “Voyage, charterhire and commission expenses.” Pool net revenues, generated by the other participants in the pooling arrangement, will be presented separately in revenue and expenses from collaborative arrangements. Each participant’s share of the net pool revenues is based on the number of days such vessels participated in the pool. Refer to note 28 for an analysis of the impact on the consolidated statement of operations for the pooling arrangement. Absent the presence of a collaborative arrangement, we present our gross share of income earned and costs incurred under the Cool Pool on the face of the consolidated statement of operations in the line items “Time and voyage charter revenues” and “Voyage, charterhire and commission expenses” respectively. For pool net revenues and expenses generated by the other participants in the pooling arrangement, we analogize these to be either the cost of obtaining a contract or the benefit of operating within the Cool Pool, and presented within the line item “Voyage, charterhire and commission expenses, net.”
Leases as lessee	Leases as lessee We determine if an arrangement contains a lease at inception. Operating leases where we are the lessee result in recognition of a right-of use (“ROU”) asset with a corresponding lease liability. The ROU asset is included in balance sheet line-items ‘Other current assets’ and ‘Other non-current assets’, depending on its maturity and the lease liability is included in balance sheet line-items ‘Other current liabilities’ and ‘Other non-current liabilities’. The ROU asset represents our right to use an underlying asset for the lease term and the lease liability represents our obligation to make lease payments per the lease agreement. Operating leases are recognized at commencement date based on the present value of lease payments over the lease term, using our incremental borrowing rate as assessed at lease commencement date. We do not separate the lease and non-lease components; they are considered a single lease component. The impact of subsequent amendments to lease agreement terms and conditions is assessed prospectively.
Insurance claims	Insurance claims We have two main types of insurance policies, being loss of hire (“LOH”) and hull and machinery (“H&M”). LOH policies provides coverage for loss of revenue for our insured vessels and related claims are generally considered gain contingencies, which are recognized when the proceeds from our insurance syndication are realized or deemed realizable, net of any deductions where applicable. LOH is recognized on the face of the consolidated statement of operations in the line item “Other operating income/(losses)”. H&M policies protects us from damages in relation to our vessels and on-board equipment. Our insurance policies are considered loss recoveries. We recognize costs incurred at the time a loss event occurs. Insurance proceeds received from insured losses are recognized when considered probable of being recovered from the counterparty and for an amount net of any deductions that may apply. H&M costs and insurance recoveries are recognized on the face of the consolidated statement of operations in line item “Vessel operating expenses”.
Cash and cash equivalents	Cash and cash equivalents We consider all demand and time deposits and highly liquid investments with original maturities of three months or less to be equivalent to cash. Amounts are presented net of allowances for expected credit losses, which are assessed based on consideration of whether the balances have short-term maturities and whether the counterparty has an investment grade credit rating, limiting any credit exposure.
Restricted cash and short-term deposits	Restricted cash and short-term deposits Restricted cash consists of bank deposits which may only be used to settle certain pre-arranged loans, bid bonds in respect of tenders for projects we have entered into, cash collateral required for certain swaps and other contracts which require us to restrict cash. Short-term deposits represent highly liquid deposits placed with financial institutions, primarily from our consolidated VIEs, which are readily convertible into known amounts of cash with original maturities of less than 12 months. Interest income earned on our short-term deposits are recognized on an accrual basis on the face of the consolidated statement of operations in line item “Interest income”. Amounts are presented net of allowances for expected credit losses, which are assessed based on consideration of whether the balances have short-term maturities and whether the counterparty has an investment grade credit rating, limiting any credit exposure.
Trade accounts receivables	Trade accounts receivables Trade receivables are presented net of allowances for expected credit losses. At each balance sheet date, all potentially uncollectible accounts are assessed individually for the purpose of determining the appropriate allowance for expected credit loss. Our trade receivables have short maturities so we have considered that forecasted changes to economic conditions will have an insignificant effect on the estimate of the allowance, except in extraordinary circumstances.
Allowance for credit losses	Allowance for credit losses Financial assets recorded at amortized cost and off-balance sheet credit exposures not accounted for as insurance (including financial guarantees) reflect an allowance for current expected credit losses (“credit losses”) over the lifetime of the instrument. The allowance for credit losses reflects a deduction to the net amount expected to be collected on the financial asset. Amounts are written off against the allowance when management believes the un-collectability of a balance is confirmed or certain. Expected recoveries will not exceed the amounts previously written-off or current credit loss allowance by financial asset category. We estimate expected credit losses based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. We have elected to calculate expected credit losses on the combined balance of both the amortized cost and accrued interest from the unpaid principal balance. Specific calculation of our credit allowances is included in the respective accounting policies included herein; all other financial assets are assessed on an individual basis calculated using the method we consider most appropriate for each asset.
Inventories	Inventories Inventories, which are comprised principally of fuel, are stated at the lower of cost and net realizable value. Cost is determined on a first-in, first-out basis.
Equity method investments	Equity method investments Equity method investments relate to our investments in entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but over which we do not exercise control or have the power to control their financial and operational policies. Investments in these entities are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the other parties’ participating rights. Under this method, we record our investment at cost and adjust the carrying amount for our share of the income or losses from these equity method investments subsequent to the date of the investment and report the recognized earnings or losses in income. Dividends received from an equity method investment reduce the carrying amount of the investment. When we decrease our investment in equity method investments but continue to retain significant influence, we recognize a gain or loss for the difference between proceeds and carrying amount of the investment sold in the statement of operations line item “Net income/(losses) from equity method investments”.
Vessels and equipment	Vessels and equipment Vessels and equipment are stated at cost less accumulated depreciation. The cost of vessels and equipment, less the estimated residual values, is depreciated on a straight-line basis over the assets’ remaining useful economic lives. Management estimates the residual values of our vessels based on broker scrap value cost of steel and aluminum times the weight of the ship noted in lightweight ton. Residual values are periodically reviewed and revised to recognize changes in conditions, new regulations or other reasons. The cost of construction of mooring equipment is capitalized and depreciated over the initial term of the related agreement. Refurbishment costs incurred during the period are capitalized as part of vessels and equipment and depreciated over the vessels’ remaining useful economic lives. Refurbishment costs are costs that appreciably increase the capacity or improve the efficiency or safety of vessels and equipment. Drydocking expenditures are capitalized when incurred and amortized over the period until the next anticipated drydocking. For vessels that are newly built or acquired, we have adopted the “built-in overhaul” method of accounting. The built-in overhaul method is based on the segregation of vessel costs into those that should be depreciated over the useful life of the vessel and those that require drydocking at periodic intervals to reflect the different useful lives of the components of the assets. The estimated cost of the drydocking component is amortized until the date of the first drydocking following acquisition, upon which the cost is capitalized and the process is repeated. When a vessel is disposed of, any unamortized drydocking expenditure is charged against income in the period of disposal. The capital costs include the addition of new equipment or modifications to the vessel which enhance or increase the operational efficiency and functionality of the vessel. These expenditures are capitalized and depreciated over the remaining useful life of the vessel. Expenditures of a routine repairs and maintenance nature that do not improve the operating efficiency or extend the useful lives of the vessels are expensed as incurred. Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRU and FLNG) 40 years Vessels - converted FSRU 20 years from conversion date Vessels - FLNG 30 years from conversion date Deferred drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years
Asset under development	Asset under developmentAn asset is classified as an asset under development when there is a firm commitment from us to proceed with the construction of the asset and the likelihood of conversion is virtually certain to occur. An asset under development is classified as non-current and is stated at cost. All costs incurred during the construction of the asset, including conversion installment payments, interest, supervision and technical costs are capitalized. Nonrefundable reimbursements are offset against the cost incurred for the construction of the asset. Interest costs directly attributable to construction of the asset are added to the cost of the asset. Capitalization ceases and depreciation commences once the asset is completed and available for its intended use.
Interest costs capitalized	Interest costs capitalized Interest is capitalized on all qualifying assets that require a period of time to get ready for their intended use. Qualifying assets consist of new vessels under construction, assets under development and vessels undergoing conversion into FSRUs or FLNGs for our own use. In addition, certain equity method investments may be considered qualifying assets prior to commencement of their planned principal operation. The interest capitalized is calculated using the rate of interest on the loan to fund the expenditure or our weighted average cost of borrowings, where appropriate, from commencement of the asset development until substantially all the activities necessary to prepare the assets for its intended use are complete. If our financing plans associate a specific borrowing with a qualifying asset, we use the rate on that borrowing as the capitali z ation rate to be applied to that portion of the average accumulated expenditures for the asset provided that does not exceed the amount of that borrowing. We do not capitali z e amounts beyond the actual interest expense incurred in the period.
Asset retirement obligation	Asset retirement obligation An asset retirement obligation (“ARO”) is a liability associated with the eventual retirement of a fixed asset.
Held-for-sale assets and disposal group	Held for sale assets and disposal group Individual assets or subsidiaries to be disposed of, by sale or otherwise in a single transaction, are classified as held for sale if all of the following criteria are met at the period end: • management, having the authority to approve the action, commits to a plan to sell the assets or subsidiaries; • the asset or subsidiaries are available for immediate sale in its (their) present condition subject only to terms that are usual and customary for such sales; • an active program to locate a buyer and other actions required to complete the plan to sell have been initiated; • the sale is probable; and • the transfer is expected to qualify for recognition as a completed sale, within one year. The term probable refers to a future sale that is likely to occur, the asset or subsidiaries (disposal group) is being actively marketed for sale at a price that is reasonable in relation to its current fair value and actions required to complete the plan indicate that it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn. A disposal group is classified as discontinued operations if either of the following criteria are met: (1) a component of an entity or group of components that has been disposed of by sale, disposed of other than by sale or is classified as held for sale that represents a strategic shift that has or will have a major effect on our financial results and operations or (2) an acquired business or non-profit activity (the entity to be sold) that is classified as held for sale on the date of the acquisition. Assets or subsidiaries held for sale are carried at the lower of their carrying amount and fair value less costs to sell. Interest and other expenses attributable to the liabilities of a disposal group classified as held for sale shall continue to be accrued. As an exception, investments in associates classified as held for sale continue to be measured in accordance with ASC 323 “Investments - Equity Method and Joint Venture”. Upon classification as held for sale, the assets are no longer depreciated. If, at any time, the criteria for held for sale is no longer met, then the asset or disposal group will be reclassified to held and used. The asset or disposal group will be valued at the lower of the carrying amount before the asset or disposal group was classified as held for sale (as adjusted for any subsequent depreciation and amortization) and its fair value. Any adjustment to the value is shown in consolidated statements of operations for the period in which the criterion for held for sale was not met. Gain or loss on disposals of held for sale assets is recognized as the difference between the fair value of consideration received and the carrying amount of the assets disposed.
Impairment of long-lived assets and asset under development	Impairment of long-lived assets and asset under development We continually monitor events and changes in circumstances that could indicate carrying amounts of long-lived assets and assets under development may not be recoverable. In assessing the recoverability of our vessels’ and assets under development’s carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual or scrap value and whether the vessel is in substance under development. Management performs an annual impairment assessment and when such events or changes in circumstances are present, we assess the recoverability of long-lived assets and assets under development by determining whether the carrying value of such assets will be recovered through undiscounted expected future cash flows. If the total of the future cash flows is less than the carrying amount of those assets, we recognize an impairment loss based on the excess of the carrying amount over their respective fair value.
Other-than temporary impairment of investments	Other-than-temporary impairment of investments Where there are indicators that fair value is below carrying value of our investments, we will evaluate these for other-than-temporary impairment. Consideration will be given to (i) the length of time and the extent to which fair value is below carrying value, (ii) the financial condition and near-term prospects of the investee and (iii) our intent and ability to hold the investment until any anticipated recovery. Where determined to be other-than-temporary impairment, we will recognize an impairment loss in the period in the line item “Net income/(losses) from equity method investments” in the consolidated statements of operations.
Investments in listed equity securities	Investments in listed equity securities Investments in listed equity securities represents ownership interests of a publicly listed entity. Investments in listed equity securities are recorded at fair value with changes in fair value reported in “Other non-operating income/(losses), net”. We classify our investment in listed equity securities in the consolidated statement of operations as non-operating because it is not integrated with our operations therefore is non-operating in nature. We use quoted market prices to determine the fair value of listed equity securities with a readily determinable fair value, unless the presence of certain restrictions warrants the application of a discount to fair value. We do not assess our investments in listed equity securities for impairment given they are carried at fair value. We classify our investments in listed equity securities as current assets because the investment is available to be sold to meet liquidity needs if necessary, even if it is not the intention to dispose of the investment in the next twelve months. Dividends received from our investments in listed equity securities are reflected as operating activities in the statement of cash flows unless such distributions relate to a return of capital in which case it is reflected as an investing activity in the statement of cash flows.
Debt	Debt Our debt has consisted of short-term and long-term debt securities, convertible debt securities and credit facilities with banks and other lenders. Debt issuances are placed directly by us or through securities dealers or underwriters and are held by financial institutions. Debt is recorded on our consolidated balance sheets at par value adjusted for unamortized discount or premium and net of unamortized debt issuance costs. Debt issuance costs directly related to the issuance of debt are amortized over the life of the debt using the effective interest method and are recorded in interest expense, net of capitalized interest. Gains and losses on the extinguishment of debt are recorded in other financial items, net on our consolidated statements of operations. Costs associated with long-term financing, including debt arrangement fees, are deferred and amortized over the term of the relevant debt under the effective interest method. Amortization of debt issuance costs is included in interest expense. These costs are presented as a deduction from the corresponding liability, consistent with debt discounts.
Derivatives	Derivatives We use derivatives to reduce market risks associated with our operations. We use interest rate swaps for the management of interest rate risk exposure. The interest rate swaps effectively convert a portion of our debt from a floating to a fixed rate over the life of the transactions without an exchange of underlying principal. We use commodity swaps to reduce our economic exposure to fluctuations in the underlying commodities for our natural-gas linked tolling fee billings. We seek to reduce our exposure to fluctuations in foreign exchange rates through the use of foreign currency forward contracts. Certain of our contracts contain embedded derivatives. We do not apply hedge accounting. All derivative instruments are initially recorded at fair value as either assets or liabilities in the accompanying consolidated balance sheets and subsequently remeasured to fair value, regardless of the purpose or intent for holding the derivative. Where the fair value of a derivative instrument is a net liability, the derivative instrument is classified in “Other current liabilities” in the consolidated balance sheets. Where the fair value of a derivative instrument is a net asset, the derivative instrument is classified in “Other current assets” and “Other non-current assets” in the consolidated balance sheets, depending on its maturity. The changes in the fair value of our interest rate and foreign exchange swap derivative instruments are recognized each period in “Gains/(losses) on derivative instruments, net” in the consolidated statements of operations while the changes in the fair value of our commodity swap derivative instruments are recognized each period in “Realized and unrealized gain/(loss) on oil and gas derivative instruments” in the consolidated statements of operations. It is our policy to enter into master netting agreements with counterparties to derivative financial instrument contracts, which give us the legal right to discharge all or a portion of the amounts owed to the counterparty by offsetting them against amounts that the counterparty owes to us. 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
Convertible bonds	Convertible bonds We account for debt instruments with convertible features in accordance with the details and substance of the instruments at the time of their issuance. For convertible debt instruments issued at a substantial premium to equivalent instruments without conversion features, or those that may be settled in cash upon conversion, it is presumed that the premium or cash conversion option represents an equity component. Accordingly, we determine the carrying amounts of the liability and equity components of such convertible debt instruments by first determining the carrying amount of the liability component by measuring the fair value of a similar liability that does not have an equity component. The carrying amount of the equity component representing the embedded conversion option is then determined by deducting the fair value of the liability component from the total proceeds from the issue. The resulting equity component is recorded, with a corresponding offset to debt discount which is subsequently amortized to interest cost using the effective interest method over the period the debt is expected to be outstanding as an additional non-cash interest expense. Transaction costs associated with the instrument are allocated pro-rata between the debt and equity components. For conventional convertible bonds which do not have a cash conversion option or where no substantial premium is received on issuance, it may not be appropriate to separate the bond into the liability and equity components.
Contingent liabilities	Contingent liabilitiesWe may, from time to time, be involved in various legal proceeding, claims, lawsuits and complaints that arise in the ordinary course of business. We will recognize a contingent liability in our financial statements if the contingency has occurred at the date of the financial statements and where we believe that the likelihood of loss was probable and the amount can be reasonably estimated. If we determine that the reasonable estimate of the loss is a range and there is no best estimate within the range, we will provide the lower amount within the range.
Pensions	Pensions Defined benefit pension costs, assets and liabilities requires significant actuarial assumptions to be adjusted annually to reflect current market and economic conditions. Our accounting policy provides that full recognition of the funded status of defined benefit pension plans is to be included within our consolidated balance sheets. The pension benefit obligation is calculated by using a projected unit credit method. Defined contribution pension costs represent our promise to make defined amounts of contributions to an individual participant’s retirement account prior to retirement, and the participant bears all the actuarial risk relating to that account once the contribution is made. Pension benefit cost is recognized in respect of the accounting period in which a contribution to the scheme is payable and is recorded in the consolidated statements of operations. A liability on our balance sheet will be recognized for any contributions due but unpaid as of the balance sheet date.
Guarantees	Guarantees Guarantees issued by us, excluding those that are guaranteeing our own performance, are recognized at fair value at the time that the guarantees are issued, or upon the deconsolidation of a subsidiary, and reported in “Other current liabilities” and “Other non-current liabilities”. A liability is recognized for the fair value of the obligation undertaken in issuing the guarantee. If it becomes probable that we will have to perform under a guarantee, we will recognize an additional liability if (and when) the amount of the loss can be reasonably estimated. The recognition of fair value is not required for certain guarantees such as the parent’s guarantee of a subsidiary’s debt to a third party. Financial guarantees are assessed for expected credit losses and any allowance is presented as a liability for off-balance sheet credit exposures where the balance exceeds the collateral provided over the remaining instrument life. The allowance is assessed at the individual guarantee level, calculated by multiplying the balance exposed on default by the probability of default and loss given default over the term of the guarantee.
Treasury shares	Treasury shares Treasury shares are recognized as a separate component of equity for an amount corresponding to the purchase consideration transferred to repurchase the shares. Upon subsequent disposal of treasury shares, any consideration is recognized directly in equity.
Stock-based compensation	Stock-based compensation Our stock-based compensation includes both stock options and restricted stock units (“RSUs”). We expense the fair value of stock-based compensation issued to employees and non-employees over the period the stock options or RSUs vest (fair value as determined for stock-based compensation uses some fair value measurement techniques, which differs from other fair value measurements). We recognize stock-based compensation cost for awards containing a service condition only on a straight-line basis over the employee’s requisite service period or the non-employee’s vesting period, unless the award contains performance and/or market conditions, in which case stock-based compensation cost is recognized using the graded vesting method. Certain stock options and RSUs provide for accelerated vesting in the event of death or disability in service or a change in control (as defined in the Golar LNG Limited Long Term Incentive Plan (the “LTIP”)). No compensation cost is recognized for stock-based compensation for which the individuals do not render the requisite service. We have elected to recognize forfeitures as they occur. The fair value of stock options is estimated using the Black-Scholes option pricing model. The fair value of RSUs is estimated using the market price of our common shares at grant date or the Monte Carlo simulation model, as appropriate. Upon eventual stock option exercises or RSU conversions, shares delivered will be made available from either our authorized unissued shares, treasury shares or repurchasing our shares in the open market.
Earnings per share	Earnings per share Basic earnings per share (“EPS”) is computed based on the income available to common shareholders and the weighted average number of shares outstanding for basic EPS. Treasury shares are not included in the calculation. Diluted EPS includes the effect of the assumed conversion of potentially dilutive instruments. Such potentially dilutive common shares are excluded when the effect would be to increase earnings per share or reduce a loss per share.
Income taxes and deferred taxes	Income taxes Income taxes are based on a separate return basis. The guidance on “Income Taxes” prescribes a recognition threshold and measurement attributes for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Penalties and interest related to uncertain tax positions are recognized in “Income taxes” in the consolidated statements of operations. Deferred taxes Deferred tax assets and liabilities are recognized principally for the expected tax consequences of temporary differences between the tax bases of assets and liabilities and their reported amounts. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Realization of the deferred income tax asset is dependent on generating sufficient taxable income in future years. Deferred tax assets and liabilities are measured at the tax rates that are expected to apply to the year when the asset is realized or the liability is settled, based on the tax rates and tax laws that have been enacted or substantively enacted at the balance sheet date. Income tax relating to items recognized directly in the statement of comprehensive income is recognized in the statement of changes in equity and not in the consolidated statements of operations.
Acquisitions	Acquisitions When the assets acquired and liabilities assumed constitute a business, then the acquisition is a business combination. If substantially all of the fair value of the gross asset acquired is concentrated in a single identifiable asset or group of similar identifiable assets, the asset is not considered a business. Business combinations are accounted for under the acquisition method. On acquisition, the identifiable assets, liabilities and contingent liabilities are measured at their fair values at the date of acquisition. Any excess of the cost of acquisition over the fair values of the identifiable net assets acquired is recognized as goodwill. In instances where the cost of acquisition is lower than the fair values of the identifiable net assets acquired (i.e. bargain purchase), the difference is credited to the statement of operations in the period of acquisition. The consideration transferred for an acquisition is measured at fair value of the consideration transferred. Acquisition related costs are expensed as incurred. The results of operations of acquired businesses are included from the date of acquisition. If the initial accounting for a business combination is incomplete by the end of the reporting period in which the combination occurs, we will recognize a measurement-period adjustment during the period in which we determine the amount of the adjustment, including the effect on earnings of any amounts we would have recorded in previous periods if the accounting had been completed at the acquisition date. For acquisitions that do not meet the definition of a business, we account for the transaction as an asset acquisition whereby the cost of the acquisition is allocated to the assets acquired and liabilities assumed and no goodwill is recognized.
Related parties	Related parties Parties are related if one party has the ability, directly or indirectly, to control the other party or exercise significant influence over the other party in making financial and operating decisions. Parties are also related if they are subject to common control or significant influence. Amounts due from related parties are presented net of allowances for expected credit losses, which are calculated using a loss rate applied against an aging matrix. Advances or loans to/from related parties are recorded at cost.
Segment reporting	Segment reporting A segment is a distinguishable component of the business that is engaged in business activities from which we earn revenues and incur expenses whose operating results are regularly reviewed by the chief operating decision maker (“CODM”), and which are subject to risks and rewards that are different from those of other segments. Our CODM deems that we provide three distinct services and operate in the following three reportable segments: “FLNG”, “Corporate and other” and “Shipping”.
Adoption of new accounting standards	Adoption of new accounting standards In March 2020, the FASB issued ASU 2020-04 Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, as amended by ASU 2021-01 Reference Rate Reform (Topic 848): Scope issued in January 2021 and ASU 2022-06 Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 issued in December 2022. This guidance provides temporary optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met, which are available for election until December 31, 2024. Modifications to contracts affected by the reference rate reform are under discussion with counterparties and optional expedients are expected to be used where available. In August 2020, the FASB issued ASU 2020-06 Debt – Debt with Conversion and Other Options (Topic 470) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Topic 815) . The amendments simplify the issuer’s accounting for convertible instruments and its application of the equity classification guidance. The new guidance eliminates some of the existing models for assessing convertible instruments, which results in more instruments being recognized as a single unit of account on the balance sheet and expands disclosure requirements. The new guidance simplifies the assessment of contracts in an entity’s own equity and existing Earnings Per Share guidance in ASC 260. We adopted this with effect from January 1, 2022. We adjusted the additional paid in capital as of January 1, 2022 in our consolidated statement of changes in equity as included herein. In May 2021, the FASB issued ASU 2021-04 Earnings Per Share (Topic 260), Debt—Modifications and Extinguishments (Subtopic 470-50), Compensation—Stock Compensation (Topic 718), and Derivatives and Hedging —Contracts in Entity’s Own Equity (Subtopic 815-40) . We adopted this with effect from January 1, 2022. The adoption of ASU 2021-04 had no impact on our consolidated financial statements. In July 2021, the FASB issued ASU 2021-05 Leases (Topic 842) – Lessors – Certain Leases with Variable Lease Payments . We adopted this with effect from January 1, 2022. The adoption of ASU 2021-05 has no impact on our consolidated financial statements. Accounting pronouncements that have been issued but not yet adopted The following table provides a brief description of other recent accounting standards that have been issued but not yet adopted as of December 31, 2022: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2021-08 Business Combinations (Topic 805) - Accounting for contract assets and contract liabilities from contracts with customers Requires contract assets and contract liabilities (i.e., deferred revenue) acquired in a business combination to be recognized and measured by the acquirer on the acquisition date in accordance with ASC 606. Generally, this new guidance will result in the acquirer recognizing contract assets and contract liabilities at the same amounts recorded by the acquiree (rather than having such amounts recognized by the acquirer at fair value in acquisition accounting, as has been historical practice). January 1, 2023 No impact expected as a result of the adoption of this ASU. Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2022-03 Fair Value Measurement (Topic 820) - Fair Value Measurement of Equity Securities Subject to Contractual Sale Restrictions This amendment is intended to reduce diversity in practice in the measurement of the fair value of equity securities subject to contractual sale restrictions. For entities that have investments in equity securities that are subject to contractual sale restrictions, the contractual restriction on the sale is not considered part of the unit of account of the equity security, is not considered when measuring fair value and additional disclosures are required. This amendment is required to be applied prospectively from date of adoption; early adoption is permitted. January 1, 2024 No impact currently expected as a result of the adoption of this ASU.

BASIS OF PREPARATION AND SIGN_3

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Schedule of useful lives applied in depreciation	Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRU and FLNG) 40 years Vessels - converted FSRU 20 years from conversion date Vessels - FLNG 30 years from conversion date Deferred drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,264 1,536,736 Additions — — — 77 77 As of December 31 1,374,607 45,771 109,094 7,341 1,536,813 Depreciation, amortization and impairment As of January 1 (223,999) (20,363) (22,767) (5,188) (272,317) Charge for the year (1) (39,449) (5,543) (5,696) (600) (51,288) Impairment (2) (72,607) — (3,548) — (76,155) As of December 31 (336,055) (25,906) (32,011) (5,788) (399,760) Net book value as of December 31, 2022 1,038,552 19,865 77,083 1,553 1,137,053 (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,287 1,536,759 Additions — — — 73 73 Write-offs (3) — — — (96) (96) As of December 31 1,374,607 45,771 109,094 7,264 1,536,736 Depreciation, amortization and impairment As of January 1 (182,474) (14,820) (15,948) (4,267) (217,509) Charge for the year (41,525) (5,543) (6,819) (1,017) (54,904) Write-offs (3) — — — 96 96 As of December 31 (223,999) (20,363) (22,767) (5,188) (272,317) Net book value as of December 31, 2021 1,150,608 25,408 86,327 2,076 1,264,419 (1) Depreciation and amortization charges for the years ended December 31, 2022 and 2021, excludes $0.5 million and, $0.5 million respectively, of amortization charges in relation to the Cameroon license fee. (2) Entry into the Arctic SPA changed the expected recovery of Golar Arctic’s carrying amount from continued use in operations over her remaining useful life, to recovery from sale, and was considered an indicator of impairment. As the revised future estimated cash flows were less than her carrying amount, an impairment charge of $76.2 million was recognized during the year ended December 31, 2022, reflecting an adjustment to her fair value (based on average broker valuation at date of measurement and represents the exit price in the principal LNG carrier sales market). (3) Write-offs relates to fully depreciated or fully amortized assets.

RECENTLY ISSUED ACCOUNTING ST_2

RECENTLY ISSUED ACCOUNTING STANDARDS (Tables)	12 Months Ended
RECENTLY ISSUED ACCOUNTING STANDARDS (Tables)	Dec. 31, 2022
Accounting Changes and Error Corrections [Abstract]
Schedule of new accounting pronouncements and changes in accounting principles	The following table provides a brief description of other recent accounting standards that have been issued but not yet adopted as of December 31, 2022: Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2021-08 Business Combinations (Topic 805) - Accounting for contract assets and contract liabilities from contracts with customers Requires contract assets and contract liabilities (i.e., deferred revenue) acquired in a business combination to be recognized and measured by the acquirer on the acquisition date in accordance with ASC 606. Generally, this new guidance will result in the acquirer recognizing contract assets and contract liabilities at the same amounts recorded by the acquiree (rather than having such amounts recognized by the acquirer at fair value in acquisition accounting, as has been historical practice). January 1, 2023 No impact expected as a result of the adoption of this ASU. Standard Description Date of Adoption Effect on our Consolidated Financial Statements or Other Significant Matters ASU 2022-03 Fair Value Measurement (Topic 820) - Fair Value Measurement of Equity Securities Subject to Contractual Sale Restrictions This amendment is intended to reduce diversity in practice in the measurement of the fair value of equity securities subject to contractual sale restrictions. For entities that have investments in equity securities that are subject to contractual sale restrictions, the contractual restriction on the sale is not considered part of the unit of account of the equity security, is not considered when measuring fair value and additional disclosures are required. This amendment is required to be applied prospectively from date of adoption; early adoption is permitted. January 1, 2024 No impact currently expected as a result of the adoption of this ASU.

SUBSIDIARIES (Tables)

SUBSIDIARIES (Tables)	12 Months Ended
SUBSIDIARIES (Tables)	Dec. 31, 2022
SUBSIDIARIES [Abstract]
Listing of significant subsidiaries	The following table lists our significant subsidiaries and their purpose as of December 31, 2022. Unless otherwise indicated, we own a 100% ownership interest in each of the following subsidiaries. Name Jurisdiction of Incorporation Purpose Gimi Holding Company Limited (1) Bermuda Holding company Golar Hilli LLC (2) Marshall Islands Holding company Golar LNG Energy Limited Bermuda Holding company Golar Hilli Corporation (2) Marshall Islands Leases the Hilli Episeyo (“ FLNG Hilli”)* Golar LNG 2216 Corporation Marshall Islands Owns the Golar Arctic Golar Gandria N.V. Curaçao Owns the Golar Gandria Gimi MS Corporation (3) Marshall Islands Owns the Gimi Golar Management (Bermuda) Limited Bermuda Management company Golar Management Limited United Kingdom Management company Golar Management AS Norway Vessel management company Golar Management Malaysia Sdn. Bhd. Malaysia Vessel management company Golar Viking Management D.O.O Croatia Vessel management company (1) In July 2019, Gimi Holding Company Limited was incorporated and is wholly owned by Golar. In October 2019, Golar transferred its ownership in Gimi MS Corporation ("Gimi MS") to Gimi Holding Company Limited. (2) In February 2018, Golar Hilli LLC was incorporated with Golar as sole member. In June 2018, the FLNG Hilli was sold to a China State Shipbuilding Corporation entity (“CSSC entity”) that subsequently leased back the vessel on a bareboat charter for a term of 10 years. In July 2018, shares in Golar Hilli Corporation. (a 89% owned subsidiary of Golar Hilli LLC) were exchanged for Hilli Common Units, Series A Special Units and Series B Special Units (note 5). (3) In November 2018, Gimi MS was incorporated with Golar as sole shareholder. In February 2019, the Gimi was transferred to Gimi MS from Golar Gimi Corporation. In April 2019, First FLNG Holdings Pte. Ltd. (“First FLNG Holdings”), a wholly-owned subsidiary of Keppel Asia Infrastructure Fund, acquired a 30% share in Gimi MS (note 5). * The above table excludes mention of the lessor variable interest entity (“lessor VIE”) that we have leased a vessel from under a finance lease. The lessor VIE is a wholly-owned, newly formed special purpose vehicle (“SPV”) of a financial institution. While we do not hold any equity investments in this SPV, we have concluded that we are the primary beneficiary of this lessor VIE and accordingly have consolidated this entity into our financial results (note 5).

VARIABLE INTEREST ENTITIES ("_2

VARIABLE INTEREST ENTITIES ("VIEs") (Tables)	12 Months Ended
VARIABLE INTEREST ENTITIES ("VIEs") (Tables)	Dec. 31, 2022
VARIABLE INTEREST ENTITIES [Abstract]
Schedule of sale leaseback transactions	The following table gives a summary of our sole sale and leaseback arrangement, including the repurchase option and obligation as of December 31, 2022: Vessel Effective from Lessor Sales value (in $ millions) Lease duration Next repurchase option (in $ millions) Date of next repurchase option Net repurchase obligation at end of lease term (in $ millions) End of lease term FLNG Hilli June 2018 CSSC entity 1,200.0 10 years 633.2 June 2023 300.0 June 2028
Summary of the bareboat charter rates per day based on Base LIBOR Interest Rate for the next five years	A summary of our payment obligations (excluding the repurchase option and obligation) under the bareboat charter with our sole lessor VIE as of December 31, 2022, are shown below: (in thousands of $) 2023 2024 2025 2026 2027 2028 FLNG Hilli (1) 115,954 110,779 105,348 100,044 94,741 22,841 (1) The payment obligations above include variable rental payments due under the lease based on assumed LIBOR plus a margin.
Schedule of assets and liabilities of lessor VIEs	The assets and liabilities of the lessor VIE that most significantly impact our consolidated balance sheets as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Assets Total Total Restricted cash and short-term deposits (note 15) 21,691 16,523 Liabilities Debt: Current portion of long-term debt and short-term debt (1) (337,547) (380,554) Long-term debt (1) (156,563) (216,313) (494,110) (596,867) (1) Where applicable, these balances are net of deferred finance charges (note 21). The most significant impact of the lessor VIE’s operations on our consolidated statements of operations and consolidated statements of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Continuing operations Statement of operations Interest expense 8,406 5,178 11,687 Statement of cash flows Net debt repayments (123,554) (97,056) (446,484) Net debt receipts 20,640 2,848 354,901 Financing costs paid — — (3,731) Discontinued operations Statement of operations Interest expense 3,814 17,492 23,046 Statement of cash flows Net debt repayments — (234,873) (104,179) Net debt receipts — 10,402 104,806 Financing costs paid — (1,568) (200) The assets and liabilities of Hilli LLC (1) that most significantly impacted our consolidated balance sheet as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Balance sheet Current assets 105,738 157,643 Non-current assets 1,481,722 1,280,217 Current liabilities (381,131) (444,352) Non-current liabilities (240,146) (270,371) (1) As Hilli LLC is the primary beneficiary of the lessor VIE (see above) the Hilli LLC balances include the lessor VIE. The most significant impacts of the lessor VIE’s operations on our consolidated statements of operations and consolidated statements of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Statement of operations Liquefaction services revenue 213,970 221,020 226,061 Realized and unrealized gain/(loss) on oil and gas derivative instruments 520,997 204,663 (42,561) Statement of cash flows Net debt repayments (123,554) (97,056) (322,304) Net debt receipts 20,640 2,848 230,721 Cash dividends paid (55,169) (33,136) (26,072) The assets and liabilities of Gimi MS that most significantly impacted our consolidated balance sheet as of December 31, 2022 and 2021, are as follows: (in thousands of $) 2022 2021 Balance sheet Current assets 12,460 7,107 Non-current assets 1,195,725 877,835 Current liabilities (10,666) (18,127) Non-current liabilities (516,298) (389,244) The most significant impacts of Gimi MS VIE’s operations on our consolidated statement of cash flows, for the years ended December 31, 2022, 2021 and 2020 are as follows: (in thousands of $) 2022 2021 2020 Statement of cash flows Additions to asset under development 267,421 213,481 217,590 Capitalized financing costs (2,748) (5,605) (11,302) Net debt receipts 125,000 110,000 170,000 Proceeds from subscription of equity interest 39,275 25,403 11,081
Schedule of other ownership interests	The ownership interests in Hilli LLC are represented by three classes of units: the Hilli Common Units, the Series A Special Units and the Series B Special Units. After the Hilli Disposal and as of December 31, 2022, the ownership structure of Hilli LLC is as follows: Percentage ownership interest Hilli Common Units Series A Special Units Series B Special Units Golar LNG Limited 44.6 % 89.1 % 89.1 % Golar Partners 50.0 % — % — % Keppel 5.0 % 10.0 % 10.0 % B&V 0.4 % 0.9 % 0.9 %

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
SEGMENT INFORMATION (Tables)	Dec. 31, 2022
Segment Reporting [Abstract]
Reconciliation of net income/(loss) to Adjusted EBITDA	A reconciliation of net income/(loss) to Adjusted EBITDA for the years ended December 31, 2022, 2021 and 2020 is as follows: (in thousands of $) 2022 2021 2020 Net income/(loss) 939,057 560,615 (167,930) Income taxes (438) 1,440 579 Income/(loss) before income taxes 938,619 562,055 (167,351) Depreciation and amortization 51,712 55,362 55,940 Impairment of long-term assets (note 19) 76,155 — — Unrealized (gain)/loss on oil and gas derivative instruments (note 8) (288,977) (179,891) 45,100 Realized and unrealized mark-to-market (gains)/losses on our investment in listed equity securities (note 9) (400,966) 295,777 — Other non-operating (income)/losses (note 9) (11,916) 66,027 (5,682) Interest income (12,225) (128) (1,479) Interest expense 19,286 34,486 39,182 (Gains)/losses on derivative instruments (note 10) (71,497) (24,348) 52,423 Other financial items, net (note 10) 5,380 (693) 557 Net (income)/loss from equity method investments (note 17) (19,041) (1,080) 537 Net loss/(income) from discontinued operations (note 14) 76,450 (625,389) 142,912 Adjusted EBITDA 362,980 182,178 162,139
Segment reporting information	Year Ended December 31, 2022 (in thousands of $) FLNG Corporate and other (2) Shipping Total results from continuing operations Statement of Operations: Total operating revenues (1) 214,825 43,230 9,685 267,740 Vessel operating expenses (58,583) (6,578) (7,641) (72,802) Voyage, charterhire and commission expenses, net (600) (34) (1,810) (2,444) Administrative (income)/expenses 22 (38,224) 102 (38,100) Project development expenses (5,335) (2,637) (45) (8,017) Realized gain on oil and gas derivative instruments (note 8) 232,020 — — 232,020 Other operating losses (15,417) — — (15,417) Adjusted EBITDA 366,932 (4,243) 291 362,980 Net income/(losses) from equity method investments — (5,193) 24,234 24,234 (1) Total operating revenues under the FLNG segment includes $0.9 million revenue from a FLNG study (note 7). (2) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Balance Sheet: Year Ended December 31, 2022 (in thousands of $) FLNG Corporate and other (1) Shipping Segment assets from continuing operations Assets held for sale Total Total assets 2,815,552 1,410,587 52,700 4,278,839 721 4,279,560 Equity method investments (note 17) — 48,669 55,439 104,108 — 104,108 Capital expenditures (note 18 and 20) 301,292 — 2,901 304,193 — 304,193 (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Year Ended December 31, 2021 (in thousands of $) FLNG Corporate and other (1) Shipping Total results from continuing operations Statement of Operations: Total operating revenues 221,020 27,777 11,476 260,273 Vessel operating expenses (51,195) (12,119) (1,052) (64,366) Voyage, charterhire and commission expenses/(income) (600) 166 (235) (669) Administrative expenses (2) (241) (34,913) (157) (35,311) Project development income/(expenses) (3,171) 507 143 (2,521) Realized gain on oil and gas derivative instruments (note 8) 24,772 — — 24,772 Adjusted EBITDA 190,585 (18,582) 10,175 182,178 Net income from equity method investments — 1,080 — — (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. (2) Included within the “Corporate and other” “administrative expenses” is $0.5 million of redundancy costs from an overhead streamlining exercise following the completion of the sale of our investments in Golar Partners and Hygo to NFE, (the “GMLP Merger” and “Hygo Merger”, respectively) (note 14). Balance Sheet: Year Ended December 31, 2021 (in thousands of $) FLNG Corporate and other (1) Shipping Segment assets from continuing operations Assets held for sale Total Total assets 2,314,342 807,276 128,901 3,250,519 1,697,776 4,948,295 Equity method investments (note 17) — 52,215 — 52,215 — 52,215 Capital expenditures (note 18) 219,582 — — 219,582 — 219,582 (1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments. Year Ended December 31, 2020 (in thousands of $) FLNG Corporate and other (1) Shipping Total results from continuing operations Statement of Operations: Total operating revenues 226,061 20,695 14,632 261,388 Vessel operating expenses/(income) (52,104) 504 (5,652) (57,252) Voyage, charterhire and commission expenses — — (1,544) (1,544) Administrative expenses (1,672) (32,068) (636) (34,376) Project development expenses (2,793) (5,711) (112) (8,616) Realized gain on oil and gas derivative instruments (note 8) 2,539 — — 2,539 Adjusted EBITDA 172,031 (16,580) 6,688 162,139 Net income/(losses) from equity method investments — (537) — —
Revenue by major customer	For the years ended December 31, 2022, 2021 and 2020, revenues from the following customer accounted for over 10% of our total operating revenues: (in thousands of $) 2022 2021 2020 Perenco and SNH (1) 213,970 80 % 221,020 85 % 226,061 86 % (1) LTA with Perenco Cameroon S.A. (“Perenco”) and Société Nationale des Hydrocarbures (“SNH”), (together, the “Customer”) in relation to the FLNG Hilli
Revenue by geographic area	The following geographical data presents our revenues from customers and total assets with respect only to our FLNG, while operating under the LTA, in Cameroon. In time and voyage charters for LNG carriers, the charterer, not us, controls the routes of our vessels. These routes can be worldwide as determined by the charterers. Accordingly, our CODM do not evaluate our performance according to geographical region. Year Ended December 31, (in thousands of $) 2022 2021 2020 Cameroon Liquefaction services revenue 213,970 221,020 226,061 Total assets 1,559,158 1,408,444 1,264,085

REVENUE (Tables)

REVENUE (Tables)	12 Months Ended
REVENUE (Tables)	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of revenue	The following table represents a disaggregation of revenue earned from contracts with customers during the years ended December 31, 2022, 2021 and 2020: Year Ended December 31, (in thousands of $) 2022 2021 2020 Base tolling fee (1) 204,501 204,501 204,501 Amortization of deferred commissioning period revenue (2) 4,120 4,120 4,220 Amortization of Day 1 gains (3) 22,608 9,712 9,950 Overproduction/underutilization (4) (20,089) 3,249 7,965 Incremental base tolling fee (5) 5,000 — — Other (6) (2,170) (562) (575) Liquefaction services revenue (10) 213,970 221,020 226,061 Management fees revenue (7) 27,916 27,411 20,695 Service revenue (8) 14,423 — — Other revenues (9) 1,746 366 — Vessel management fees and other revenues (10) 44,085 27,777 20,695 (1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel, and at an increased rate when the oil price is greater than $60 per barrel. The oil price above the base rate is recognized as a derivative and included in “Realized and unrealized gain/(loss) on oil and gas derivative instruments” in the consolidated statements of operations (note 8). (2) Customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term was deferred (note 23 and 24) and recognized evenly over the contract term of the LTA. (3) Day 1 gain results from amount established on the initial recognition of the FLNG Hilli ’ s oil derivative instrument embedded in the LTA and the FLNG Hilli's gas derivative instruments pursuant to LTA Amendment 3 (note 23 and 24). These amounts were deferred on initial recognition and amortized evenly over the contract term. (4) In March 2021, we signed an agreement with the Customer (“LTA Amendment 2”), to change the contract term from one linked to fixed capacity of 500.0 billion cubic feet to one of a fixed term, terminating on July 18, 2026. This amendment also permits billing adjustments for amounts over or under the annual contracted capacity in a given contract year (“overproduction” or “underutilization”, respectively), commencing from the 2019 contract year. Amounts for overproduction were invoiced at the end of a given contract year, while amounts for underutilization (which is capped per contract year) will be a reduction against our final invoice to the Customer at the end of the LTA in July 2026. Pursuant to LTA Amendment 2, we have billed and recognized overproduction revenue in relation to excess production over contracted annual based capacity during contract years 2020 and 2021. Due to a production shortfall of the FLNG Hilli for the 2022 contract year, we recognized a non-current contract liability for this underutilization of $35.8 million (note 24). The presentation of this shortfall is bifurcated as reductions to the “Liquefaction services revenue” and "Other operating income” line items in the consolidated statements of operations amounting to $20.1 million and $15.7 million, respectively. (5) In July 2021, we entered into LTA Amendment 3 which increased the annual capacity utilization of FLNG Hilli by 0.2 million tons of LNG, for the 2022 contract year. In July 2022, the Customer exercised its option pursuant to LTA Amendment 3 for 0.2 million tons (out of 0.4 million tons) from January 2023 to the end of the LTA in July 2026. The combined effect results in annual contracted base capacity of 1.4 million tons of LNG from January 1, 2022 to the end of the LTA. The tolling fee is linked to TTF and the Euro/U.S. Dollar foreign exchange movements. The contractual floor rate is recognized in “Liquefaction services revenue” and the tolling fee above the contractual floor rate is recognized as a derivative in “Realized and unrealized gain/(loss) on oil and gas derivative instruments”, in the consolidated statements of operations (note 8). (6) “Other” comprised of accrued demurrage cost of $1.6 million (2021: $nil), which we recognized in the period in which the delay occurred. The unwinding of liquidated damages recognized prior to the commencement of the contract term of $0.6 million (2021: $0.6 million) were deferred (note 24) and released evenly over the contract term. (7) Comprised of ship management, administrative and vessel operation and maintenance services. We entered into several agreements to provide ship management and administrative services to external customers and related parties (note 14 and 28). (8) In August 2022, we entered into a development agreement with Snam to provide drydocking, site commissioning and hook-up services for the Golar Tundra (the “Development Agreement”), which it acquired from us in May 2022 (note 14.2). The Development Agreement includes contractual fixed payments recognized over the period of time that we provide the services to Snam. We assessed this to be a single performance obligation to the customer that is satisfied over time (from the period of entry into the agreement to delivery of the fully commissioned FSRU to our customer), with progress over time measured using an input method of recognition based on our efforts expended over the contract term, reflecting our past experience with comparable projects for our owned vessels, as determined using hours expended by our project team. As of December 31, 2022, we recognized services revenue and an associated contract liability of $14.4 million and $4.2 million (note 23), respectively. The remaining unsatisfied services revenue performance obligation of $4.9 million is expected to be recognized within a year. (9) Included in “Other revenues” are revenues from a FLNG study of $0.9 million which was completed in December 2022 (assessed as a single performance obligation recognized at a point in time) and sub-leasing income of $0.4 million (note 13). (10) Liquefaction services revenue and the revenue from a FLNG study of $0.9 million (within vessel management fees and other revenues) were included under our “FLNG” segment while the remaining vessel management fees and other revenues were recognized under our “Corporate and Other” segment.
Contract assets and liabilities	The following table represents our contract assets and liabilities balances as of December 31, 2022 and 2021: Year Ended December 31, (in thousands of $) 2022 2021 Contract assets 21,297 21,778 Current contract liabilities (1) (8,398) (4,221) Non-current contract liabilities (2) (3) (54,018) (14,515) Total contract liabilities (62,416) (18,736) Opening balance on January 1 (18,736) (22,856) Deferral of revenue (62,223) — Recognition of unearned revenue 18,543 4,120 Closing balance on December 31 (62,416) (18,736) (1) In August 2022, we entered into the Development Agreement and had received advance payments of $18.6 million, of which we had recognized services revenue of $14.4 million during the year ended December 31, 2022. (2) In May 2022, we entered into a sale and purchase agreement (the “Arctic SPA”) with SNAM RETE GAS S.p.A (part of Snam), pursuant to which, upon receipt of a notice to proceed, we will convert LNG carrier Golar Arctic to a FSRU, deliver, install and connect her to Snam’s mooring located offshore Italy, and following completion of commissioning activities and provisional acceptance, her eventual sale to Snam. The Arctic SPA includes contractual fixed payments (recognized over the period of time that we provide the services to Snam). As of December 31, 2022, we recognized a non-current contract liability of $7.8 million (note 24). (3) Included within “Non-current contract liabilities” is the advance payment received in relation to the Arctic SPA of $7.8 million, underutilization liability of $35.8 million and deferred commissioning revenue in relation to the Hilli of $10.4 million (note 24) . 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 3.5 years, including the components of transaction price described above.

REALIZED AND UNREALIZED GAIN__2

REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of realized and unrealized gain/(loss) on the oil and gas derivative instruments	The realized and unrealized gain/(loss) on the oil and gas derivative instruments is comprised of the following: (in thousands of $) Year Ended December 31, 2022 2021 2020 Realized gain on FLNG Hilli’s gas derivative instrument 139,929 — — Realized gain on FLNG Hilli’s oil derivative instrument 110,696 24,772 2,539 Realized mark-to-market (“MTM”) adjustment on commodity swap derivatives (18,605) — — Realized gain on oil and gas derivative instruments, net 232,020 24,772 2,539 Unrealized gain on FLNG Hilli’s gas derivative instrument (note 20) 121,959 51,286 — (in thousands of $) Year Ended December 31, 2022 2021 2020 Unrealized MTM adjustment for commodity swap derivatives 111,703 1,665 — Unrealized gain/(loss) on FLNG Hilli’s oil derivative instrument (note 20) 55,315 126,940 (45,100) Unrealized gain/(loss) on oil and gas derivative instruments, net 288,977 179,891 (45,100) Realized and unrealized gain/(loss) on oil and gas derivative instruments (note 27) 520,997 204,663 (42,561)

OTHER NON-OPERATING INCOME_(L_2

OTHER NON-OPERATING INCOME/(LOSSES) (Tables)	12 Months Ended
OTHER NON-OPERATING INCOME/(LOSSES) (Tables)	Dec. 31, 2022
Other Income and Expenses [Abstract]
Schedule of other non-operating income/(losses)	Other non-operating income/(losses), net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16) (1) 400,966 (295,777) — UK tax lease liability (note 29) 7,148 (71,739) — Dividend income from our investment in listed equity securities 4,768 5,588 — Gain on disposal of the LNG Croatia (2) — — 5,682 Others — 124 — Other non-operating income/(losses) 412,882 (361,804) 5,682 (1) “Investment in listed equity securities”, included in balance sheet line-item “Other current assets” (note 16), relates to our equity holding in NFE of 5.3 million and 18.6 million shares as of December 31, 2022 and 2021, respectively. During the years ended December 31, 2022 and 2021, we recognized $350.9 million unrealized MTM gains and $295.8 million unrealized MTM losses, respectively. In 2022, we sold 13.3 million of our NFE Shares (note 14.3) at a price range between $40.80 and $58.29 per share for an aggregate consideration of $625.6 million, inclusive of $3.8 million fees, which resulted in realized MTM gains of $50.1 million. There was no comparable sale of our NFE Shares during the year ended December 31, 2021. (2) In March 2019, we entered into agreements with LNG Hrvatska d.o.o. (“LNG Hrvatska”),relating to the conversion and subsequent sale of the converted carrier, LNG Croatia into a FSRU. In addition, we also entered into an agreement to operate and maintain the FSRU, LNG Croatia for a minimum of 10 years (“LNG Hrvatska O&M Agreement”). In December 2020, the converted FSRU, LNG Croatia was accepted by LNG Hrvatska and we recognized a gain on disposal of $5.7 million which comprised of cash proceeds of $193.3 million, partially offset by the carrying value of the converted vessel of $187.6 million. Other financial items, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Financing arrangement fees and other related costs (1) (9,340) (1,201) (1,409) Amortization of debt guarantees 2,657 2,569 4,111 Foreign exchange gain/(loss) on operations 1,598 (384) (3,107) Other (295) (291) (152) Other financials items, net (5,380) 693 (557) (1) Financing arrangement fees and other related costs for the year ended December 31, 2022 mainly comprised of (i) $4.9 million write-off of deferred financing fees and expenses in relation to an undrawn corporate bilateral facility, the availability of which expired in June 2022; (ii) $2.3 million loss on partial repurchase of the Unsecured Bonds (note 21) in December 2022 (note 21); and (iii) $1.4 million commitment fees paid in relation to the undrawn portion of the Corporate RCF, which was canceled in November 2022 (note 21).

GAINS_(LOSSES) ON DERIVATIVE _2

GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative instruments, gain (loss)	Gains/(losses) on derivative instruments, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Unrealized MTM adjustment for interest rate swap (“IRS”) derivatives 72,269 27,016 (38,601) Net interest expense on undesignated IRS derivatives (772) (2,908) (6,215) Foreign exchange gain/(loss) on terminated undesignated foreign exchange swaps — 240 (2,556) Unrealized MTM adjustment for equity derivatives — — (5,051) Gains/(losses) on derivative instruments, net 71,497 24,348 (52,423)
Components of other financial items, net	Other non-operating income/(losses), net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16) (1) 400,966 (295,777) — UK tax lease liability (note 29) 7,148 (71,739) — Dividend income from our investment in listed equity securities 4,768 5,588 — Gain on disposal of the LNG Croatia (2) — — 5,682 Others — 124 — Other non-operating income/(losses) 412,882 (361,804) 5,682 (1) “Investment in listed equity securities”, included in balance sheet line-item “Other current assets” (note 16), relates to our equity holding in NFE of 5.3 million and 18.6 million shares as of December 31, 2022 and 2021, respectively. During the years ended December 31, 2022 and 2021, we recognized $350.9 million unrealized MTM gains and $295.8 million unrealized MTM losses, respectively. In 2022, we sold 13.3 million of our NFE Shares (note 14.3) at a price range between $40.80 and $58.29 per share for an aggregate consideration of $625.6 million, inclusive of $3.8 million fees, which resulted in realized MTM gains of $50.1 million. There was no comparable sale of our NFE Shares during the year ended December 31, 2021. (2) In March 2019, we entered into agreements with LNG Hrvatska d.o.o. (“LNG Hrvatska”),relating to the conversion and subsequent sale of the converted carrier, LNG Croatia into a FSRU. In addition, we also entered into an agreement to operate and maintain the FSRU, LNG Croatia for a minimum of 10 years (“LNG Hrvatska O&M Agreement”). In December 2020, the converted FSRU, LNG Croatia was accepted by LNG Hrvatska and we recognized a gain on disposal of $5.7 million which comprised of cash proceeds of $193.3 million, partially offset by the carrying value of the converted vessel of $187.6 million. Other financial items, net is comprised of the following: Year Ended December 31, (in thousands of $) 2022 2021 2020 Financing arrangement fees and other related costs (1) (9,340) (1,201) (1,409) Amortization of debt guarantees 2,657 2,569 4,111 Foreign exchange gain/(loss) on operations 1,598 (384) (3,107) Other (295) (291) (152) Other financials items, net (5,380) 693 (557) (1) Financing arrangement fees and other related costs for the year ended December 31, 2022 mainly comprised of (i) $4.9 million write-off of deferred financing fees and expenses in relation to an undrawn corporate bilateral facility, the availability of which expired in June 2022; (ii) $2.3 million loss on partial repurchase of the Unsecured Bonds (note 21) in December 2022 (note 21); and (iii) $1.4 million commitment fees paid in relation to the undrawn portion of the Corporate RCF, which was canceled in November 2022 (note 21).

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
INCOME TAXES (Tables)	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Components of income tax expense (benefit)	The components of income tax benefit/(expense) are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Current tax expense (520) (1,445) (375) Deferred tax benefit/(expense) 958 5 (204) Total income tax benefit/(expense) 438 (1,440) (579)
Schedule of effective income tax rate reconciliation	The income taxes for the years ended December 31, 2022, 2021 and 2020 differed from the amount computed by applying the Bermuda statutory income tax rate of 0% as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Effect of movement in deferred tax balances 958 5 (204) Effect of adjustments in respect of current tax in prior periods 346 (232) 40 Effect of taxable income in various countries (866) (1,213) (415) Total tax benefit/(expense) 438 (1,440) (579)

EARNINGS_(LOSS) PER SHARE (Tabl

EARNINGS/(LOSS) PER SHARE (Tables)	12 Months Ended
EARNINGS/(LOSS) PER SHARE (Tables)	Dec. 31, 2022
Earnings Per Share [Abstract]
Components of earnings per share, basic and diluted	The components of the numerator for the calculation of basic and diluted EPS/(LPS) are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Net income/(loss) net of non-controlling interests - continuing operations - basic and diluted 872,429 (175,960) (93,991) Net (loss)/income net of non-controlling interests - discontinued operations - basic and diluted (84,656) 589,811 (179,566) The components of the denominator for the calculation of basic and diluted EPS/(LPS) are as follows: Year ended December 31, (in thousands) 2022 2021 2020 Basic: Weighted average number of common shares outstanding 107,860 109,644 97,554 Dilutive: Dilutive impact of share options and RSUs (1) 682 — — Weighted average number of common shares outstanding 108,542 109,644 97,554 EPS/(LPS) per share are as follows: Year ended December 31, 2022 2021 2020 Basic EPS/(LPS) from continuing operations $ 8.09 $ (1.60) $ (0.96) Diluted EPS/(LPS) from continuing operations (1) $ 8.04 $ (1.60) $ (0.96) Basic and diluted EPS from discontinued operations $ (0.79) $ 5.38 $ (1.84) (1) The effects of stock awards and convertible bonds have been excluded from the calculation of diluted EPS/LPS from continuing operations for the years ended December 31, 2021 and 2020 because the effects were anti-dilutive.

OPERATING LEASES (Tables)

OPERATING LEASES (Tables)	12 Months Ended
OPERATING LEASES (Tables)	Dec. 31, 2022
Leases [Abstract]
Schedule of payments to be received by maturity	The minimum contractual future revenues to be received on a time charter agreement in respect of the Golar Arctic as of December 31, 2022, are as follows: Year ending December 31 (in thousands of $) 2023 15,420 Total minimum contractual future revenues 15,420
Operating lease income	The components of operating lease income were as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Operating lease income 8,857 11,476 13,887 Variable lease income (1) 828 — 745 Total operating lease income (2) 9,685 11,476 14,632 (1) “Variable lease income” is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases. “Time and voyage charter revenues”
Operating lease costs	The components of operating lease cost were as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Operating lease cost 4,160 5,899 4,338 Variable lease cost (1) 1,479 1,621 4,000 Total operating lease cost (2) 5,639 7,520 8,338 (1) “Variable lease cost” is excluded from lease payments that comprise the operating lease liability. (2) Total operating lease cost is included in the consolidated statement of operations line-items “Vessel operating expenses” and “Administrative expenses”.
Schedule of maturity of operating lease liabilities	The maturity of our lease liabilities is as follows: Year ending December 31 (in thousands of $) 2023 1,328 2024 851 2025 1,151 2026 1,088 2027 and thereafter 730 Total minimum lease payments 5,148

ASSETS AND LIABILITIES HELD F_2

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
Schedule of disposal groups, including discontinued operations	The net income/(loss) from discontinued operations for the years ended December 31, 2022, 2021 and 2020 are as follows: Year Ended December 31, 2022 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total (Loss)/income from discontinued operations (194,500) 4,880 — (189,620) (Loss)/ gain on disposal (10,060) 123,230 — 113,170 Net (loss)/income from discontinued operations (204,560) 128,110 — (76,450) Year Ended December 31, 2021 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total (Loss)/income from discontinued operations 54,534 2,806 (6,892) 50,448 Gain on disposal — — 574,941 574,941 Net income from discontinued operations 54,534 2,806 568,049 625,389 Year Ended December 31, 2020 (in thousands of $) CoolCo TundraCo Golar Partners and Hygo Total Income/(loss) from discontinued operations 36,699 (3,622) (175,989) (142,912) Net income/(loss) from discontinued operations 36,699 (3,622) (175,989) (142,912) The following table contains the financial statement line-items presented as discontinued operations following the CoolCo Disposal: Year ended December 31, (in thousands of $) 2022 2021 2020 Time and voyage charter revenues 37,289 161,957 164,740 Vessel and other management fees 1,815 — — Vessel operating expenses (8,466) (49,446) (46,400) Voyage, charterhire and commission expenses (1,229) (709) (11,228) Administrative expenses 1,906 476 (772) Project development expenses (62) (362) (275) Depreciation and amortization (5,807) (43,497) (44,437) Impairment of long-lived assets (1) (218,349) — — Other operating income 4,374 5,020 3,262 Operating (loss)/income (188,529) 73,439 64,890 Other non-operating losses — (124) — Interest income 4 7 67 Interest expense (4,725) (18,087) (26,954) Other financial items, net (799) (401) (902) Pretax (loss)/income from discontinued operations (194,049) 54,834 37,101 Income taxes (451) (300) (402) (Loss)/income from discontinued operations (194,500) 54,534 36,699 Loss on CoolCo Disposal (2) (10,060) — — Net (loss)/income from discontinued operations (204,560) 54,534 36,699 (1) Impairment of long-live assets relates to the impairment charge on the held for sale vessels recognized in accordance with ASC 360 Property, plant and equipment , following their classification as held-for-sale. (2) Loss on CoolCo Disposal comprised of carrying values of the assets and liabilities disposed of $355.4 million, partially offset by the proceeds received of $218.2 million cash consideration and 12.5 million shares of CoolCo valued at $127.1 million (based on the respective share price on the phased completion dates). The following table contains the financial statement line-items forming the assets and liabilities classified as held for sale: (in thousands of $) 2022 2021 ASSETS Current assets Cash and cash equivalents 369 34,173 Restricted cash and short-term deposits — 43,311 Trade accounts receivable 16 767 Other current assets 29 1,965 Total current assets held for sale 414 80,216 Non-current assets Restricted cash — 780 Vessels and equipment, net 51 1,383,760 Other non-current assets 151 697 Total non-current assets held for sale 202 1,385,237 Total assets held for sale 616 1,465,453 LIABILITIES Current liabilities Current portion of long-term debt and short-term debt — (338,501) Trade accounts payables (3) (7,272) Accrued expenses (180) (59,246) Other current liabilities (76) (11,640) Total current liabilities held for sale (259) (416,659) Non-current liabilities Long-term debt — (292,322) Other non-current liabilities (114) (11,978) Total non-current liabilities held for sale (114) (304,300) Total liabilities held for sale (373) (720,959) The following table contains the financial statement line-items presented as discontinued operations following TundraCo's Disposal: Year ended December 31, (in thousands of $) 2022 2021 2020 Time and voyage charter revenues 27,776 29,534 12,509 Vessel operating expenses (5,119) (6,511) (5,274) Voyage, charterhire and commission expenses (10,004) (9,396) 138 Administrative expenses (16) (89) (163) Depreciation and amortization (2,955) (7,092) (7,546) Operating income/(loss) 9,682 6,446 (336) Interest income — 4 27 Interest expense (4,649) (2,589) (3,219) Other financial items, net (153) (1,055) (94) Pretax income/(loss) from discontinued operations 4,880 2,806 (3,622) Income taxes — — — Income/(loss) from discontinued operations 4,880 2,806 (3,622) Gain on disposal of discontinued operations (1) 123,230 — — Net income/(loss) from discontinued operations 128,110 2,806 (3,622) (1) Gain on TundraCo Disposal comprised of (i) cash proceeds received of $352.5 million, (ii) a partially offset by the net asset value of Golar LNG NB 13 Corporation of $229.0 million and (iii) related fees incurred in relation to disposal of $0.3 million. The following table contains the financial statement line-items forming the assets and liabilities classified as held for sale: (in thousands of $) 2022 2021 ASSETS Current assets Cash and cash equivalents — 2,605 Trade accounts receivable — 70 Other current assets 105 153 Total current assets held for sale 105 2,828 Non-current assets Vessels and equipment, net — 229,495 Total non-current assets held for sale — 229,495 Total assets held for sale 105 232,323 (in thousands of $) 2022 2021 LIABILITIES Current liabilities Current portion of long-term debt and short-term debt — (9,911) Trade accounts payables — (204) Accrued expenses — (737) Other current liabilities — (2,325) Total current liabilities held for sale — (13,177) Non-current liabilities Long-term debt — (145,768) Total non-current liabilities held for sale — (145,768) Total liabilities held for sale — (158,945) The net income/(loss) of equity method investments from discontinued operations for the period ended April 15, 2021 and the year ended December 31, 2020 is as follows: Period January 1, 2021 to April 15, 2021 Year ended December 31, (in thousands of $) 2021 2020 Net income/(loss) from equity method investments in Golar Partners 8,116 (136,832) Net loss from equity method investments in Hygo (15,008) (39,157) Loss from discontinued operations (6,892) (175,989) Gain on disposal of equity method investments (1) 574,939 — Net income/(loss) from discontinued operations 568,047 (175,989) (1) Gain on disposal of discontinued operations comprised of (i) proceeds received of $876.3 million; (ii) release of our tax indemnity guarantee liability to Golar Partners of $2.0 million; (iii) a partial offset by the carrying values of our investment in affiliates disposed of $257.3 million as of April 15, 2021; (iv) realized accumulated comprehensive losses on disposal of investment in affiliates of $43.4 million; and (v) fees incurred in relation to disposals of $2.7 million. The summarized financial information of Golar Partners and Hygo shown on a 100% basis are as follows: (in thousands of $) April 15, 2021 December 31, 2020 Golar Partners Hygo Golar Partners Hygo Balance Sheet Current assets 85,738 97,509 146,821 109,596 Non-current assets 1,742,835 949,265 1,880,840 917,976 Current liabilities (1,152,473) (144,146) (832,277) (97,245) Non-current liabilities (17,965) (461,291) (570,063) (453,278) Non-controlling interests (82,339) (15,250) 82,112 13,557 (in thousands of $) April 15, 2021 December 31, 2020 Golar Partners Hygo Golar Partners Hygo Statement of Operations Revenue 78,389 13,749 284,734 47,295 Net income/(loss) (1) 28,952 (110,735) 18,077 (61,859)

RESTRICTED CASH AND SHORT-TER_2

RESTRICTED CASH AND SHORT-TERM DEPOSITS (Tables)	12 Months Ended
RESTRICTED CASH AND SHORT-TERM DEPOSITS (Tables)	Dec. 31, 2022
Restricted Cash and Investments [Abstract]
Components of restricted cash and cash equivalents	Our restricted cash and short-term deposits balances are as follows: (in thousands of $) 2022 2021 Restricted cash in relation to the FLNG Hilli (1) 60,952 60,720 Restricted cash and short-term deposits held by lessor VIEs (2) 21,691 16,523 Restricted cash in relation to the Golar Arctic guarantees (3) 38,822 — Restricted cash relating to sale of LNG Croatia (4) 11,504 11,328 Restricted cash relating to office lease 1,074 2 Restricted cash related to Hygo performance guarantee (5) — 1,500 Restricted cash in relation to liability for UK tax leases (6) (note 29) — 16,000 Total restricted cash and short-term deposits 134,043 106,073 Less: Amounts included in current restricted cash and short-term deposits (21,693) (34,025) Long-term restricted cash 112,350 72,048 (1) In November 2015, in connection with the issuance of a $400 million letter of credit (“LC”) by a financial institution to the Customer of the FLNG Hilli , we recognized an initial cash collateral of $305.0 million to support the FLNG Hilli performance guarantee. Under the provisions of the LC, the terms allow for a stepped reduction in the value of the guarantee over time and a corresponding reduction to the cash collateral requirements. In May 2021, the FLNG Hilli had achieved 3.6 million tons of LNG production, reducing the LC to $100 million and the cash collateral to $61.0 million as of December 31, 2022. In November 2016, after we satisfied certain conditions precedent, the LC originally issued with an initial expiration date of December 31, 2018, was re-issued and automatically extends, on an annual basis, until the tenth anniversary of the acceptance date of the FLNG Hilli , unless the bank exercises its option to exit from the arrangement by giving a three months’notice prior to the next annual renewal date. (2) These are amounts held by lessor VIE that we are required to consolidate under U.S. GAAP into our financial statements as a VIE (note 5). (3) In connection with the Arctic SPA, we are required to provide a performance guarantee of €26.9 million and three advance repayment guarantees totaling €163.9 million, which corresponds to the three installment payments from Snam. The performance guarantee and the advance repayment guarantees secures our contractual and performance obligations of the conversion of the Golar Arctic , respectively. As of December 31, 2022, we recognized cash collateral for the performance guarantee and first of three advance repayment guarantees of $29.8 million (€26.9 million) and $9.0 million (€8.1 million), respectively. The performance guarantee and three advance repayments guarantees will remain as restricted cash until the final acceptance date of October 2027 and the provisional acceptance date of December 2025, respectively. (4) In connection with the LNG Hrvatska O&M Agreement, we are required to maintain two performance guarantees, one in the amount of €9.3 million and one in the amount of $1.3 million, both of which will remain restricted throughout the 10-year term until December 2030. (5) In connection with the disposal of Hygo, we provided a $1.5 million performance guarantee to the senior lenders of Centrais Eléctricas de Sergipe S.A. to enable those lenders to waive their requirement for consent in the event of a change of control and extend the technical completion date of the power plant. The performance guarantee was subsequently released in November 2022. (6) The lessor for the six legacy UK leases had a first priority security interest in relation to the Golar Gandria and second priority interests in relation to the Golar Tundra and the Golar Frost

OTHER CURRENT ASSETS (Tables)

OTHER CURRENT ASSETS (Tables)	12 Months Ended
OTHER CURRENT ASSETS (Tables)	Dec. 31, 2022
Other Assets [Abstract]
Schedule of other current assets	Other current assets consists of the following: (in thousands of $) 2022 2021 Investment in listed equity securities (1) 224,788 450,225 MTM asset on TTF linked commodity swap derivatives (note 27) 73,583 1,753 Receivable from TTF linked commodity swap derivatives 4,638 — Interest receivable from money market deposits 3,617 — Prepaid expenses 2,760 2,692 Receivable from IRS derivatives 1,923 — TTF linked commodity swap collateral (2) — 6,940 Gas derivative instrument (note 27) — 79,578 Other receivables (3) 3,233 2,559 Other current assets 314,542 543,747 (1) “Investment in listed equity securities” as of December 31, 2022 and 2021 comprised of our 5.3 million and 18.6 million NFE Shares, and associated dividend receivable of $nil and $0.6 million, respectively. Dividend receivable is presented in the consolidated statement of operations line-item “Other non-operating income/(losses)”. (2) “TTF linked commodity swap collateral” relates to the cash amount required by the swap counterparty, held at measurement date, which is reactive to the daily fluctuations of the market value of the financial instrument. (3) Included in “Other receivables” as of December 31, 2022 is $1.8 million reimbursable from Snam in relation to the Development Agreement.

EQUITY METHOD INVESTMENTS (Tabl

EQUITY METHOD INVESTMENTS (Tables)	12 Months Ended
EQUITY METHOD INVESTMENTS (Tables)	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Participation percentages, carrying amounts and components of non-consolidated investees	At December 31, 2022 and 2021, we have the following participation in investments that are recorded using the equity method: 2022 2021 Egyptian Company for Gas Services S.A.E (“ECGS”) 50.0 % 50.0 % Avenir LNG Limited (“Avenir”) 23.5 % 23.5 % CoolCo 8.3 % — % Aqualung Carbon Capture AS (“Aqualung”) 4.4 % — % The carrying amounts of our equity method investments as of December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 CoolCo 55,439 — Avenir 41,790 47,913 ECGS 4,503 4,302 Aqualung 2,376 — Equity method investments 104,108 52,215 The components of our equity method investments are as follows: (in thousands of $) 2022 2021 Balance as of January 1, 52,215 44,385 Additions 129,662 6,750 Net income 19,041 1,080 Guarantee fee 1,708 — Employee stock compensation 127 — Share of other comprehensive losses (797) — Proceeds from disposal (97,848) — Balance as of December 31, 104,108 52,215 Summarized financial information of our equity method investments shown on a 100% basis are as follows: (in thousands of $) December 31, 2022 CoolCo ECGS Avenir Aqualung Balance Sheet Current assets 145,338 36,504 34,028 5,900 Non-current assets 1,912,723 97 270,177 159 Current liabilities (278,589) (25,501) (69,509) (359) Non-current liabilities (1,063,959) (931) (92,694) — Statement of Operations Revenue 256,434 58,680 62,875 245 Net income/(loss) 110,744 713 (16,217) (2,830) (in thousands of $) December 31, 2021 CoolCo ECGS Avenir Aqualung Balance Sheet Current assets 79,293 41,690 59,741 73 Non-current assets 1,387,215 107 208,949 — Current liabilities (417,453) (31,028) (38,557) (70) Non-current liabilities (306,000) (931) (66,179) — Statement of Operations Revenue 171,919 80,972 16,538 — Net (loss)/income 48,368 55 7,119 (472)

ASSET UNDER DEVELOPMENT (Tables

ASSET UNDER DEVELOPMENT (Tables)	12 Months Ended
ASSET UNDER DEVELOPMENT (Tables)	Dec. 31, 2022
Extractive Industries [Abstract]
Schedule of assets under development	(in thousands of $) 2022 2021 Opening asset under development balance 877,838 658,247 Additions 221,184 178,377 Interest costs capitalized 53,010 41,214 Closing asset under development balance 1,152,032 877,838
Schedule of contractual obligations by fiscal year maturity	As of December 31, 2022, the estimated timing of the outstanding payments in connection with the Gimi FLNG conversion is as follows: (in thousands of $) Period ending December 31, 2023 385,785 2024 139,669 525,454

VESSELS AND EQUIPMENT, NET (Tab

VESSELS AND EQUIPMENT, NET (Tables)	12 Months Ended
VESSELS AND EQUIPMENT, NET (Tables)	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
Components of vessels and equipment, net	Useful lives applied in depreciation are as follows: Vessels (excluding converted FSRU and FLNG) 40 years Vessels - converted FSRU 20 years from conversion date Vessels - FLNG 30 years from conversion date Deferred drydocking expenditure 5 years Deferred drydocking expenditure - FLNG 20 years Mooring equipment - FLNG 8 years Office equipment and fittings 3 to 6 years (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,264 1,536,736 Additions — — — 77 77 As of December 31 1,374,607 45,771 109,094 7,341 1,536,813 Depreciation, amortization and impairment As of January 1 (223,999) (20,363) (22,767) (5,188) (272,317) Charge for the year (1) (39,449) (5,543) (5,696) (600) (51,288) Impairment (2) (72,607) — (3,548) — (76,155) As of December 31 (336,055) (25,906) (32,011) (5,788) (399,760) Net book value as of December 31, 2022 1,038,552 19,865 77,083 1,553 1,137,053 (in thousands of $) Vessels and equipment Mooring equipment Deferred Drydocking expenditure Office equipment and fittings Total Cost As of January 1 1,374,607 45,771 109,094 7,287 1,536,759 Additions — — — 73 73 Write-offs (3) — — — (96) (96) As of December 31 1,374,607 45,771 109,094 7,264 1,536,736 Depreciation, amortization and impairment As of January 1 (182,474) (14,820) (15,948) (4,267) (217,509) Charge for the year (41,525) (5,543) (6,819) (1,017) (54,904) Write-offs (3) — — — 96 96 As of December 31 (223,999) (20,363) (22,767) (5,188) (272,317) Net book value as of December 31, 2021 1,150,608 25,408 86,327 2,076 1,264,419 (1) Depreciation and amortization charges for the years ended December 31, 2022 and 2021, excludes $0.5 million and, $0.5 million respectively, of amortization charges in relation to the Cameroon license fee. (2) Entry into the Arctic SPA changed the expected recovery of Golar Arctic’s carrying amount from continued use in operations over her remaining useful life, to recovery from sale, and was considered an indicator of impairment. As the revised future estimated cash flows were less than her carrying amount, an impairment charge of $76.2 million was recognized during the year ended December 31, 2022, reflecting an adjustment to her fair value (based on average broker valuation at date of measurement and represents the exit price in the principal LNG carrier sales market). (3) Write-offs relates to fully depreciated or fully amortized assets.

OTHER NON-CURRENT ASSETS (Table

OTHER NON-CURRENT ASSETS (Tables)	12 Months Ended
OTHER NON-CURRENT ASSETS (Tables)	Dec. 31, 2022
OTHER NON-CURRENT ASSETS [Abstract]
Components of other non-current assets	Other non-current assets is comprised of the following: (in thousands of $) 2022 2021 Gas derivative instrument (note 27) 196,184 — Oil derivative instrument (note 27) 182,795 127,480 MTM asset on IRS derivatives (note 27) 54,970 — MTM asset on TTF linked commodity swap derivatives (note 27) 39,785 — Operating lease right-of-use-assets (1) 5,653 10,293 Others (2) 32,652 3,673 Other non-current assets 512,039 141,446 (1) Operating lease right-of-use-assets mainly comprise of our office leases. (2) Included within “Others” for the year ended December 31, 2022 is expenditure on engineering services and long lead items of $16.7 million and $10.4 million, respectively, for our Mark II FLNG, one of our FLNG design models for prospective conversion of an existing LNG carrier to a FLNG and $2.9 million of engineering and other professional fees in preparation for the conversion of the Golar Arctic pursuant to the terms of Arctic SPA .

DEBT (Tables)

DEBT (Tables)	12 Months Ended
DEBT (Tables)	Dec. 31, 2022
Debt Disclosure [Abstract]
Components of long-term debt (including related parties)	(in thousands of $) 2022 2021 Total debt, net of deferred finance charges (1,189,324) (1,623,300) Less: Current portion of long-term debt and short-term debt 344,778 703,170 Long-term debt (844,546) (920,130)
Future repayments of outstanding debt (including related parties)	The outstanding debt, gross of deferred finance charges, as of December 31, 2022 is repayable as follows: Year ending December 31 Golar debt VIE debt (1) Total debt (in thousands of $) 2023 (7,294) (337,666) (344,960) 2024 (43,756) (60,600) (104,356) 2025 (217,363) (60,600) (277,963) 2026 (58,333) (35,500) (93,833) 2027 (58,333) — (58,333) 2028 and thereafter (330,834) — (330,834) Total (715,913) (494,366) (1,210,279) Deferred finance charges 20,699 256 20,955 Total debt net of deferred finance charges (695,214) (494,110) (1,189,324) (1) These amounts relate to a certain lessor entity (for which legal ownership resides with a financial institution) that we are required to consolidate into our financial statements as a VIE (note 5).
Components of debt	At December 31, 2022 and 2021, our debt was as follows: (in thousands of $) 2022 2021 Maturity date Gimi facility (535,000) (410,000) March 2030 Unsecured Bonds (159,029) (299,403) October 2025 Golar Arctic facility (21,884) (29,178) October 2024 2017 Convertible bonds — (315,646) Subtotal (excluding lessor VIE debt) (715,913) (1,054,227) CSSC VIE debt - FLNG Hilli facility (494,366) (597,280) Repayable on demand/2026 Total debt (gross) (1,210,279) (1,651,507) Less: Deferred finance charges 20,955 28,207 Total debt, net of deferred financing costs (1,189,324) (1,623,300)
Schedule of lessor VIE debt	The following loan relates to our lessor VIE entity, the CSSC entity that we consolidate as a VIE. Although we have no control over the funding arrangement of this entity, we consider ourselves the primary beneficiary of this VIE and therefore are required to consolidate this loan facility into our financial results (note 5). Facility Effective from SPV Loan counterparty Loan facility at inception (in $ millions) Loan facility at December 31, 2022(in $ millions) Loan duration/maturity Interest Hilli (1) June 2018 Fortune Lianjing Shipping S.A. CSSC entity (840.0) (217.3) 8 years non-recourse LIBOR plus margin (120.0) (277.1) Repayable on demand Nil (1) In July 2019, the SPV, Fortune Lianjiang Shipping S.A., repaid $150.0 million to the interest-bearing facility and subsequently drew down $150.0 million from an internal loan with the CSSC entity. In March, 2020, the SPV, Fortune Lianjiang Shipping S.A., repaid $215.2 million to the interest-bearing facility and subsequently drew down $223.0 million from the internal loan with the CSSC entity. The vessel in the table above is secured as collateral against these long-term loans (note 29).

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	12 Months Ended
ACCRUED EXPENSES (Tables)	Dec. 31, 2022
Payables and Accruals [Abstract]
Components of accrued expenses	Accrued expenses is comprised of the following: (in thousands of $) 2022 2021 Interest (13,514) (13,767) Vessel related (1) (10,795) (7,925) Administrative related (2) (8,039) (10,122) Current tax payable (485) (1,058) Accrued expenses (32,833) (32,872) (1) “Vessel related” accrued expenses is comprised of vessel operating expenses such as crew wages, vessel supplies, routine repairs, maintenance, drydocking, lubricating oils and insurance. (2) “Administrative related” accrued expenses is comprised of general overhead including personnel costs, legal and professional fees, costs associated with project development, property costs and other general expenses.

OTHER CURRENT LIABILITIES (Tabl

OTHER CURRENT LIABILITIES (Tables)	12 Months Ended
OTHER CURRENT LIABILITIES (Tables)	Dec. 31, 2022
Other Liabilities, Current [Abstract]
Components of other current liabilities	(in thousands of $) 2022 2021 Day 1 gain deferred revenue - current portion (1) (note 24) (12,783) (38,242) Deferred revenue (6,080) (5,584) Contract liability for other revenue (note 5) (4,177) — Demurrage cost (note 5) (1,608) — Current portion of operating lease liability (note 13) (1,328) (3,006) MTM liability on TTF linked commodity swap derivatives (note 27) — (88) Liability for UK tax leases (note 29) — (71,739) MTM liability on interest rate swaps (note 27) — (17,300) Other payables (2) (1,469) (455) Other current liabilities (27,445) (136,414) (1) Current portion of Day 1 gain deferred on initial recognition of the oil and gas derivative instruments embedded in the LTA (note 7). As of December 31, 2022 and 2021, the Day 1 gain deferred revenue - current portion relating to FLNG Hilli’s oil and gas derivative instruments is $10.0 million and $2.8 million; $10.0 million and $28.3 million, respectively.

OTHER NON-CURRENT LIABILITIES (

OTHER NON-CURRENT LIABILITIES (Tables)	12 Months Ended
OTHER NON-CURRENT LIABILITIES (Tables)	Dec. 31, 2022
Other Liabilities, Noncurrent [Abstract]
Components of other long-term liabilities	Other non-current liabilities is comprised of the following: (in thousands of $) 2022 2021 Underutilization liability (note 7) (35,806) — Day 1 gain deferred revenue (1) (31,720) (34,221) Pension obligations (note 25) (24,269) (31,357) Deferred commissioning period revenue (2) (10,396) (14,515) Golar Arctic’s contract liability (3) (7,816) — Non-current portion of operating lease liabilities (note 13) (3,587) (7,136) Other payables (4) (6,834) (5,730) Other non-current liabilities (120,428) (92,959) (1) Non-current portion of Day 1 gain deferred on initial recognition of the oil and gas derivative instruments embedded in the LTA (note 7). As of December 31, 2022 and 2021, the non-current portion of the Day 1 gain deferred revenue relating to FLNG Hilli’s oil and gas derivative instruments is $24.5 million and $7.2 million; $34.2 million and $nil, respectively. (2) FLNG Hilli’s Customer billing during the commissioning period, prior to vessel acceptance and commencement of the LTA, which is considered an upfront payment for services. These amounts billed are recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the Customer’s acceptance of the FLNG Hilli . The current portion of deferred commissioning period billing is included in “Other current liabilities” (note 23). (3) “ Golar Arctic’s contract liability” represents the first advance received from Snam in relation to the Arctic SPA (note 7 and 15). (4) Included in “Other payables” are an asset retirement obligation of $5.7 million and $5.3 million for the years ended December 31, 2022 and 2021, respectively. The corresponding asset of $4.7 million is recorded within vessels and equipment, net (note 19).

PENSIONS (Tables)

PENSIONS (Tables)	12 Months Ended
PENSIONS (Tables)	Dec. 31, 2022
Retirement Benefits [Abstract]
Components of net periodic benefit cost	The components of net periodic benefit costs are as follows: Year ended December 31, (in thousands of $) 2022 2021 2020 Service cost (75) (120) (155) Interest cost (1,087) (879) (1,271) Expected return on plan assets 254 214 318 Recognized actuarial loss (774) (1,131) (848) Net periodic benefit cost (1,682) (1,916) (1,956)
Reconciliation of benefit obligation	The change in projected benefit obligation and plan assets and reconciliation of funded status for the year ended December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 Reconciliation of benefit obligation: Benefit obligation at January 1 47,215 54,122 Service cost 75 120 Interest cost 1,087 879 Actuarial gain (1) (10,106) (4,081) Foreign currency exchange rate changes (1,227) (120) Benefit payments (2,966) (3,705) Benefit obligation at December 31 34,078 47,215 (1) Actuarial gain is sensitive to changes in key actuarial assumptions specifically discount rates, mortality rates and assumed future salary increases.
Reconciliation of fair value of plan assets	The accumulated benefit obligation at December 31, 2022 and 2021 was $33.9 million and $46.7 million, respectively. (in thousands of $) 2022 2021 Reconciliation of fair value of plan assets: Fair value of plan assets at January 1 15,858 16,864 Actual return on plan assets (4,392) (46) Employer contributions 2,900 2,900 Foreign currency exchange rate changes (1,591) (155) Benefit payments (2,966) (3,705) Fair value of plan assets at December 31 9,809 15,858
Reconciliation of funded status	Employer contributions and benefits paid under the pension plans include $2.9 million paid from employer assets for the years ended December 31, 2022 and 2021. (1) Our defined benefit pension plan is comprised of two schemes as follows: December 31, 2022 December 31, 2021 (in thousands of $) UK Scheme Marine Scheme Total UK Scheme Marine Scheme Total Fair value of benefit obligation (7,073) (27,005) (34,078) (11,608) (35,607) (47,215) Fair value of plan assets 8,801 1,008 9,809 15,077 781 15,858 Funded (unfunded) status at end of year 1,728 (25,997) (24,269) 3,469 (34,826) (31,357)
Asset allocation of retirement schemes	The fair value of our plan assets, by category, as of December 31, 2022 and 2021 are as follows: (in thousands of $) 2022 2021 Equity securities 8,801 15,077 Cash 1,008 781 9,809 15,858 The asset allocation for our Marine scheme at December 31, 2022 and 2021, by asset category are as follows: Marine scheme 2022 (%) 2021 (%) Cash 100 100 Total 100 100 The asset allocation for our UK scheme at December 31, 2022 and 2021, by asset category are as follows: UK scheme 2022 (%) 2021 (%) Equity 100 100 Total 100 100
Expected contributions to pension schemes	We are expected to make the following contributions to the schemes during the year ended December 31, 2023, as follows: (in thousands of $) UK scheme Marine scheme Employer contributions — 2,900
Expected pension disbursements	We are expected to make the following pension disbursements as follows: (in thousands of $) UK scheme Marine scheme 2023 340 2,600 2024 370 2,500 2025 470 2,400 2026 390 2,300 2027 400 2,200 2028 - 2032 2,140 9,500
Weighted average assumptions used	The weighted average assumptions used to determine the benefit obligation for our defined benefit pension plans for the years ended December 31 are as follows: 2022 2021 Discount rate 4.94 % 2.43 % Rate of compensation increase 2.61 % 2.70 % The weighted average assumptions used to determine the net periodic benefit cost for our defined benefit pension plans for the years ended December 31 are as follows: 2022 2021 Discount rate 4.93 % 2.44 % Expected return on plan assets 1.81 % 1.31 % Rate of compensation increase 2.49 % 2.75 %

SHARE CAPITAL AND SHARE BASED_2

SHARE CAPITAL AND SHARE BASED COMPENSATION (Tables)	12 Months Ended
SHARE CAPITAL AND SHARE BASED COMPENSATION (Tables)	Dec. 31, 2022
SHARE CAPITAL AND SHARE OPTIONS [Abstract]
Authorized and issue share capital	As of December 31, 2022 and 2021, our authorized and issued share capital is as follows: Authorized share capital: (in thousands of $, except per share data) 2022 2021 150,000,000 (2021: 150,000,000) common shares of $1.00 each 150,000 150,000 Issued share capital: (in thousands of $, except per share data) 2022 2021 107,225,832 (2021: 108,222,604) outstanding issued common shares of $1.00 each 107,226 108,223 (number of shares) 2022 2021 As of January 1 108,222,604 109,943,594 Repurchase and cancellation of treasury shares (1) (1,189,653) (1,984,647) Vesting of RSUs 186,881 263,657 Share options exercised 6,000 — As of December 31 107,225,832 108,222,604
Weighted average assumptions used	The weighted average assumptions as of the May 2021 grant date are noted in the table below: 2021 Risk free interest rate 0.2 % Expected volatility of common stock 85.0 % Expected dividend yield 0.0 % Expected term of options (in years) 2.3 years 2020 Remaining performance period 2.8 years Contractual term 3.0 years Expected dividend yield 0.0 % Risk free interest rate 0.42 % Golar volatility 84 % Share price at grant date $ 7.49
Summary of stock option activity	A summary of the share options movements during the year ended December 31, 2022 is presented below: Shares Weighted average exercise price Weighted average remaining contractual term Options outstanding at December 31, 2021 1,505 $ 17.65 1.6 Forfeited during the year (334) $ 21.17 Exercised during the year (6) $ 26.90 Lapsed during the year (128) $ 26.44 Options outstanding at December 31, 2022 1,037 $ 15.37 1.0 Options outstanding and exercisable at: December 31, 2022 662 $ 17.87 0.8 December 31, 2021 755 $ 24.28 0.8 December 31, 2020 1,717 $ 24.46 1.2 Year ended December 31, (in thousands of $) 2022 2021 2020 Total fair value of share options fully vested in the year 1,958 1,595 3,175 Compensation cost recognized in the consolidated statement of income 1,971 1,434 2,274 Share options cost capitalized* — 16 110 *Relates to capitalized costs on share options awarded to employees directly involved in certain vessel conversion projects.
Summary of time-based RSU activity	A summary of time-based RSU activities for the year ended December 31, 2022 is presented below: Shares (in ‘000s) Weighted average grant date fair value per share Weighted average remaining contractual term Non-vested RSUs at December 31, 2021 343 9.71 1.1 Granted during the year 97 22.52 Vested during the year (187) 11.28 Forfeited during the year (35) 9.63 Non-vested RSUs at December 31, 2022 218 14.09 1.2
Summary of performance-based RSU activity	A summary of performance-based RSU activity for the year ended December 31, 2022 is presented below: Shares (in ‘000s) Weighted average grant date fair value per share Weighted average remaining contractual term Non-vested performance based RSUs at December 31, 2021 28 6.25 1.2 Granted during the year 42 22.79 Forfeited during the year (1) 22.79 Non-vested performance based RSUs at December 31, 2022 69 16.05 1.6 Year ended December 31, (in thousands of $) 2022 2021 2020 Compensation cost recognized in the consolidated statement of income 1,522 1,774 2,739 RSU cost capitalized * 198 322 295 *Relates to capitalized costs on RSUs awarded to employees directly involved in certain vessel conversion projects.

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
FINANCIAL INSTRUMENTS (Tables)	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Interest rate swap transactions	As of December 31, 2022 and 2021, we were party to the following interest rate swap transactions involving the payment of fixed rates in exchange for LIBOR as summarized below: Instrument Year end Notional value Maturity dates Fixed interest rates Interest rate swaps: Receiving floating, pay fixed 2022 740,000 2024/2029 1.69% to 2.37% Receiving floating, pay fixed 2021 505,000 2024/2029 1.69% to 2.37%
Fair value of derivative instruments on a gross basis	Instrument Year end Notional quantity (MMBtu) Maturity date Fixed price/MMBtu Commodity swap derivatives: Receiving fixed, pay floating 2022 4,839,000 2023 - 2024 $49.50 to $51.20 Receiving fixed, pay floating 2021 1,209,753 2023 - 2024 $23.25 to $28.00 The following table summarizes the fair value of our derivative instruments on a gross basis (none of which have been designated as hedges) recorded in our consolidated balance sheets as of December 31, 2022 and 2021 : Balance sheet classification 2022 2021 (in thousands of $) Asset derivatives Gas derivative instrument Other current assets and other non-current assets (note 16 and note 20) 196,184 79,578 Oil derivative instrument Other non-current assets (note 20) 182,795 127,480 Commodity swaps Other current assets and other non-current assets (note 16 and note 20) 113,368 1,753 Interest rate swaps Other non-current assets (note 20) 54,970 — Total asset derivatives 547,317 208,811 Liability derivatives Interest rate swaps Other current liabilities (note 23) — (17,300) Commodity swap Other current liabilities (note 23) — (88) Total liability derivatives — (17,388)
Fair value hierarchy of derivative and non-derivative financial instruments	The carrying values and estimated fair values of our financial instruments at December 31, 2022 and 2021 are as follows: 2022 2022 2021 2021 (in thousands of $) Fair value hierarchy Carrying value Fair value Carrying value Fair value Non-Derivatives: Cash and cash equivalents (1) Level 1 878,838 878,838 231,849 231,849 Restricted cash and short-term deposits (2) Level 1 134,043 134,043 106,073 106,073 Trade accounts receivable (2) Level 1 41,545 41,545 28,912 28,912 Receivable from TTF linked commodity swap derivatives (2) Level 1 4,638 4,638 — — Receivable from IRS derivatives (2) Level 1 1,923 1,923 — — Investment in listed equity securities (3) Level 1 224,788 224,788 449,666 449,666 TTF linked commodity swap collateral (2) (note 16) Level 1 — — 6,940 6,940 Trade accounts payable (3) Level 1 (8,983) (8,983) (4,929) (4,929) Assets held for sale (note 14) Level 2 721 721 1,697,776 1,697,776 Liabilities held for sale (note 14) Level 2 (373) (373) (879,904) (879,904) Current portion of long-term debt and short-term debt (2) (4) (5) Level 2 (344,960) (344,960) (388,005) (388,005) Current portion of 2017 Convertible Bonds (4) (6) Level 2 — — (315,646) (316,561) Long-term debt (6) (7) Level 2 (706,290) (706,290) (947,855) (947,855) Long-term debt - Unsecured Bonds (4) (6) Level 1 (159,029) (158,092) — — Derivatives: Oil and gas derivative instruments (7) Level 2 378,979 378,979 207,058 207,058 Asset on IRS derivatives (8) Level 2 54,970 54,970 — — Liability on IRS derivatives (8) Level 2 — — (17,300) (17,300) Asset on TTF linked commodity swap derivatives (8) (9) Level 2 113,368 113,368 1,753 1,753 Liability on TTF linked commodity swap derivatives (8) (9) Level 2 — — (88) (88) (1) These instruments carrying value is highly liquid and is a reasonable estimate of fair value. (2) These instruments are considered to be equal to their estimated fair value because of their near term maturity. (3) “Investment in listed equity securities” refers to our NFE Shares (note 16). The fair value is based on the NFE closing share price as of the balance sheet date. (4) Our debt obligations are recorded at amortized cost in the consolidated balance sheets. The amounts presented in the table are gross of the deferred charges amounting to $21.0 million and $28.2 million at December 31, 2022 and 2021, respectively. (5) The estimated fair values for both the floating long-term debt and short-term debt are considered to be equal to the carrying value since they bear variable interest rates, which are adjusted on a quarterly or six-monthly basis. (6) The estimated fair values of our unsecured 2017 Convertible Bonds and Unsecured Bonds are based on their quoted market prices as of the balance sheet date. In February 2022, following the listing of the Unsecured Bonds, the fair value hierarchy transferred from Level 2 to Level 1. (7) The fair value of the oil and gas derivative instruments is determined using the estimated discounted cash flows of the additional payments due to us as a result of oil and gas prices moving above the contractual floor price over the remaining term of the LTA. Significant inputs used in the valuation of the oil and gas derivative instruments include the Euro/U.S. Dollar exchange rates based on the forex forward curve for the gas derivative instrument and management’s estimate of an appropriate discount rate and the length of time necessary to blend the long-term and short-term oil and gas prices obtained from quoted prices in active markets. (8) 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. The credit exposure of certain derivative instruments is represented by the fair value of contracts with a positive value at the end of each period, reduced by the effects of master netting arrangements. (9) Does not include collateral posted with counterparties to our TTF commodity swaps. We have recognized cash collateral receivable of $nil and $6.9 million as of December 31, 2022 and 2021, respectively, in relation to our TTF commodity swaps (note 16).
Offsetting assets and liabilities	The amounts presented in our consolidated balance sheet in relation to interest rate and commodity swaps have not been offset. For our commodity swaps, if we were to offset and record the asset and liability balances of derivatives on a net basis, the amounts presented in our consolidated balance sheets as of December 31, 2022 and 2021 would be adjusted as in the following table: 2022 2021 Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount Gross amounts presented in the consolidated balance sheet Gross amounts not offset in the consolidated balance sheet subject to netting agreements Net amount (in thousands of $) Commodity swaps Total asset derivatives 113,368 — 113,368 1,753 (88) 1,665 Total derivative liabilities — — — (88) 88 —

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
RELATED PARTY TRANSACTIONS (Tables)	Dec. 31, 2022
Related Party Transactions [Abstract]
Schedule of related party transactions	Net revenues: The transactions with CoolCo during the year ended December 31, 2022 consists of the following: (in thousands of $) 2022 Management and administrative services revenue (1) 3,124 Ship management fees revenue (2) 1,249 Ship management fees expense (3) (5,811) Debt guarantee fees (4) 837 Commitment fee (5) 115 Total (486) (1) Management and administrative services revenue – Golar Management Limited (“Golar Management”), a wholly-owned subsidiary of Golar, and Golar Management (Bermuda) Ltd, entered into the CoolCo TSA (subsequently replaced with the CoolCo ASA), both described further in note 14.1, pursuant to which we provided corporate administrative services to CoolCo. The CoolCo ASA expires on June 30, 2023. (2) Ship management fee revenue – We provided commercial and technical management to the LNG carriers prior to disposal to CoolCo under the existing management agreements, however the CoolCo TSA revised the annual management fee payable to us per vessel. On June 30, 2022, upon completion of the CoolCo Disposal, the ship management agreements were terminated. (3) Ship management fee expense – Following completion of the ManCo SPA with CoolCo in June 2022, we entered into ship management agreements with CoolCo, to provide commercial and technical management for certain of our LNG carriers, amounting to (i) $0.6 million ship management fees for the Golar Arctic and Golar Tundra and (ii) $0.1 million fees incurred for FLNG crewing for the year ended December 31, 2022. We also entered into an agreement to sub-contract our contractual vessel management obligations for the LNG Croatia and NFE’s fleet of vessels to CoolCo amounting to $5.1 million for the for the year ended December 31, 2022. The ship management fee revenue of $4.8 million received in relation to NFE’s fleet of vessels is passed on at cost to CoolCo as our subcontracting ship management expenses presented on “Administrative expenses” in the consolidated statements of operations. (4) Debt guarantee fees – We agreed to remain as the guarantor of the payment sale and lease-back obligations of two of the disposed subsidiaries, which are the disponent owners of the Golar Ice and the Golar Kelvi n, in exchange for a guarantee fee of 0.5% on the outstanding principal balances, which as of December 31, 2022 is $210.3 million. The compensation amounted to $0.8 million for the year ended December 31, 2022. (5) Commitment fee – We advanced a two years revolving credit facility of $25.0 million to CoolCo, which remains undrawn as of December 31, 2022. The facility bears a fixed interest rate and commitment fee on the undrawn loan of 5% and 0.5% per annum, respectively. The commitment fee amounted to $0.1 million for the year ended December 31, 2022. Receivables: The balances with CoolCo and its subsidiaries as of December 31, 2022 consisted of the following: (in thousands of $) 2022 Balance due from CoolCo and subsidiaries (6) 394 (6) Balances due from CoolCo and its subsidiaries - Amounts due to/from CoolCo and its subsidiaries are comprised primarily of unpaid management servic es, amounts arising from the results of CoolCo ’ s vessels participating in the Cool Pool, revolving credit facility, commitment fees and other related arrangements. Payables and receivables are generally settled quarterly in arrears. Balances owing to or due from CoolCo and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business.
Transactions with existing related parties	Net revenues/(expenses): The transactions with other related parties for the years ended December 31, 2022, 2021 and 2020 consisted of the following: (in thousands of $) 2022 2021 2020 Avenir (1) 246 468 980 Magni Partners (2) (32) (189) (606) ECGS (3) — 1,482 — Total 214 1,761 374 Receivables: The balances with other related parties as of December 31, 2022 and 2021 consisted of the following: (in thousands of $) 2022 2021 Avenir (1) 3,472 3,225 Magni Partners (2) 81 81 Total 3,553 3,306 (1) Avenir entered into agreements to compensate Golar in relation to the provision of certain debt guarantees relating to Avenir and its subsidiaries. This compensation amounted to $0.1 million, $0.5 million and $1.0 million for the years ended December 31, 2022, 2021 and 2020, respectively. In October 2021, we advanced a one year revolving shareholder loan of $5.3 million to Avenir, of which $1.8 million was drawn as of December 31, 2022. In October 2022, the revolving shareholder loan was extended to three years. The facility bears a fixed interest rate of 5% per annum. The aggregated interest and commitment fee receivable on the undrawn portion of the loan amounted to $143 thousand and $28 thousand, for the years ended December 31, 2022 and 2021, respectively. (2) Magni Partners - Tor Olav Trøim is the founder of, and partner in, Magni Partners (Bermuda) Limited (“Magni Partners”), a privately held Bermuda company, and is the ultimate beneficial owner of the company. Receivables and payables from Magni Partners comprise primarily of the cost (without mark-up) or part cost of personnel employed by Magni Partners who have provided advisory and management services to Golar. These costs do not include any payment for any services provided by Tor Olav Trøim himself. (3) We chartered our former LNG carrier, the Golar Ice to ECGS during the year ended December 31, 2021. There was no comparable transaction for the year ended December 31, 2022.
Transactions with former related parties	Net revenues: The following tables represents the transactions before these companies ceased to be our related parties for the years ended December 31, 2021 and 2020: (in thousands of $) 2021 2020 Transactions Golar Partners and subsidiaries 3,986 13,521 Hygo and subsidiaries 3,631 10,887 Borr Drilling 348 384 2020 Bulkers 111 45 OneLNG 64 — Total 8,140 24,837 Receivables: The balances before these companies ceased to be our related parties as of December 31, 2021 consisted the following: (in thousands of $) 2021 Balances Borr Drilling 149 2020 Bulkers 29 Total 178 The following table represent the transactions with Golar Partners and its subsidiaries for the period from January 1, 2021 to April 15, 2021 and for the year ended December 31, 2020: (in thousands of $) Period January 1, 2021 to April 15, 2021 Year Ended December 31, 2020 Management and administrative services revenue 1,717 7,941 Ship management fees revenue 2,251 5,263 Interest income on short-term loan 18 317 Total 3,986 13,521 (in thousands of $) Period January 1, 2021 to April 15, 2021 Year Ended December 31, 2020 Management and administrative services revenue 2,051 5,281 Ship management fees income 904 1,780 Debt guarantee compensation 676 3,826 Total 3,631 10,887

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
COMMITMENTS AND CONTINGENCIES (Tables)	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Schedule of assets pledged	Year ended December 31, (in thousands of $) 2022 2021 Book value of vessels secured against long-term loans (1) 1,115,500 1,242,343 (1) This excludes the Gimi which is classified as “Assets under development” (note 18) and secured against the Gimi debt facility (note 21).

GENERAL - Narrative (Details)

GENERAL - Narrative (Details) - LNG carrier	Dec. 31, 2022 vessel
LNG carrier
Ownership Interests [Line Items]
Number of carriers owned and operated	2
FSRU, contracted for conversion \| Golar Artic
Ownership Interests [Line Items]
Number of carriers owned and operated	1
FLNG
Ownership Interests [Line Items]
Number of carriers owned and operated	2

BASIS OF PREPARATION AND SIGN_4

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES - Property and Equipment (Details)	12 Months Ended
	Dec. 31, 2022
Vessels (excluding converted FSRU and FLNG)
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	40 years
Vessels - converted FSRU
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	20 years
FLNG
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	30 years
Deferred drydocking expenditure
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	5 years
Deferred drydocking expenditure - FLNG
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	20 years
Mooring equipment - FLNG
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	8 years
Minimum \| Office equipment and fittings
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	3 years
Maximum \| Office equipment and fittings
Property, Plant and Equipment [Line Items]
Useful lives applied in depreciation	6 years

BASIS OF PREPARATION AND SIGN_5

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Details)	12 Months Ended
	Dec. 31, 2022 segment service
Trading Activity, Gains and Losses, Net [Line Items]
Number of reportable segments \| segment	3
Number of services \| service	3
Deferred drydocking expenditure
Trading Activity, Gains and Losses, Net [Line Items]
Period until next anticipated drydocking	5 years

SUBSIDIARIES - Narrative (Detai

SUBSIDIARIES - Narrative (Details)	12 Months Ended
SUBSIDIARIES - Narrative (Details)	Dec. 31, 2022	Apr. 30, 2019	Jul. 12, 2018
Gimi Holding Company Limited
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Hilli LLC
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Lease duration (in years)	10 years
Golar LNG Energy Limited
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Hilli Corporation
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%		89%
Golar LNG 2216 Corporation
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Gandria N.V.
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Gimi MS Corporation
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Management (Bermuda) Limited
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Management Limited
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Management AS
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Management Malaysia SDN. BDH.
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
Golar Viking Management D.O.O
Ownership Interests [Line Items]
Percentage ownership in subsidiary (in percent)	100%
First FLNG Holdings \| Gimi MS Corporation
Ownership Interests [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)		30%

VARIABLE INTEREST ENTITIES ("_3

VARIABLE INTEREST ENTITIES ("VIEs") - Narrative (Details) $ / shares in Units, $ in Thousands		12 Months Ended
	Dec. 31, 2021 USD ($)	Dec. 31, 2022 USD ($) $ / barrel class_of_unit vessel $ / shares	Dec. 31, 2021 USD ($) vessel	Dec. 31, 2020 USD ($)	Apr. 16, 2019
Variable Interest Entity [Line Items]
Non-controlling interest		$ 182,707	$ 25,888	$ 4,809
Number of classes of units \| class_of_unit		3
Oil price per barrel (in dollars per barrel) \| $ / barrel		60
Gimi MS \| FLNG
Variable Interest Entity [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)					30%
Golar Hilli LLC \| Hilli Common Units
Variable Interest Entity [Line Items]
Entitlement to distributions (in percent)		5%
Entitlement to vehicle expansion capacity distributions (in percent)		5%
Golar Hilli LLC \| Series A Special Units
Variable Interest Entity [Line Items]
Redemption price for series A special Units (in dollars per share) \| $ / shares		$ 1
Golar Hilli LLC \| Series B Special Units
Variable Interest Entity [Line Items]
Entitlement to distributions (in percent)		95%
Vessels disposal group
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transactions disposed \| vessel		7
Non-controlling Interests
Variable Interest Entity [Line Items]
Non-controlling interest		$ 182,707	$ 25,888	$ 4,809
Variable interest entity, primary beneficiary
Variable Interest Entity [Line Items]
Number of vessels in sale and leaseback transaction \| vessel		1	8
Lease duration (in years)		10 years
Variable interest entity, primary beneficiary \| CMBL lessor VIE
Variable Interest Entity [Line Items]
Non-controlling interest	$ 25,900
Sales-type lease, net investment in lease, purchase	$ 103,300

VARIABLE INTEREST ENTITIES ("_4

VARIABLE INTEREST ENTITIES ("VIEs") - Summary of the Sale and Leaseback Arrangement (Details) - Variable interest entity, primary beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)
Variable Interest Entity [Line Items]
Lease duration (in years)	10 years
CSSC entity \| FLNG Hilli
Variable Interest Entity [Line Items]
Sales value (in $ millions)	$ 1,200
Lease duration (in years)	10 years
Next repurchase option (in $ millions)	$ 633.2
Net repurchase obligation at end of lease term (in $ millions)	$ 300

VARIABLE INTEREST ENTITIES ("_5

VARIABLE INTEREST ENTITIES ("VIEs") - Summary of Bareboat Charters (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Variable Interest Entity [Line Items]
2023	$ 1,328
2024	851
2025	1,151
2026	1,088
2027	730
CSSC entity \| Variable interest entity, primary beneficiary \| FLNG Hilli
Variable Interest Entity [Line Items]
2023	115,954
2024	110,779
2025	105,348
2026	100,044
2027	94,741
2028	$ 22,841

VARIABLE INTEREST ENTITIES ("_6

VARIABLE INTEREST ENTITIES ("VIEs") - Summary of assets and liabilities of lessor VIEs (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Assets
Restricted cash and short-term deposits (note 15)	$ 134,043	$ 106,073
Liabilities
Current portion of long-term debt and short-term debt	(344,778)	(703,170)
Long-term debt	(844,546)	(920,130)
Total liabilities	(1,379,386)	(2,770,378)
Statement of operations
Interest expense	19,286	34,486	$ 39,182
Continuing operations
Statement of cash flows
Net debt repayments	(719,917)	(289,148)	(745,445)
Net debt receipts	276,640	411,866	624,901
Capitalized financing costs	(9,599)	(13,300)	(13,300)
Discontinued operations
Statement of cash flows
Net debt repayments	(158,000)	(268,107)	(189,088)
Net debt receipts	0	168,402	104,806
Capitalized financing costs	(280)	(3,700)	(1,277)
Variable interest entity, primary beneficiary
Assets
Restricted cash and short-term deposits (note 15)	21,691	16,523
Liabilities
Current portion of long-term debt and short-term debt	(337,547)	(380,554)
Long-term debt	(156,563)	(216,313)
Total liabilities	(494,110)	(596,867)
Variable interest entity, primary beneficiary \| Continuing operations
Statement of operations
Interest expense	8,406	5,178	11,687
Statement of cash flows
Net debt repayments	(123,554)	(97,056)	(446,484)
Net debt receipts	20,640	2,848	354,901
Capitalized financing costs	0	0	(3,731)
Variable interest entity, primary beneficiary \| Discontinued operations
Statement of operations
Interest expense	3,814	17,492	23,046
Statement of cash flows
Net debt repayments	0	(234,873)	(104,179)
Net debt receipts	0	10,402	104,806
Capitalized financing costs	$ 0	$ (1,568)	$ (200)

VARIABLE INTEREST ENTITIES ("_7

VARIABLE INTEREST ENTITIES ("VIEs") - Golar Hilli (Details) - Golar Hilli LLC	Jul. 12, 2018
Golar LNG Limited \| Hilli Common Units
Schedule of Equity Method Investments [Line Items]
Percentage ownership by wholly owned subsidiary	44.60%
Golar LNG Limited \| Series A Special Units
Schedule of Equity Method Investments [Line Items]
Percentage ownership by wholly owned subsidiary	89.10%
Golar LNG Limited \| Series B Special Units
Schedule of Equity Method Investments [Line Items]
Percentage ownership by wholly owned subsidiary	89.10%
Golar Partners \| Hilli Common Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	50%
Golar Partners \| Series A Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	0%
Golar Partners \| Series B Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	0%
Keppel \| Hilli Common Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	5%
Keppel \| Series A Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	10%
Keppel \| Series B Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	10%
B&V \| Hilli Common Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	0.40%
B&V \| Series A Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	0.90%
B&V \| Series B Special Units
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, ownership percentage by noncontrolling owners (in percent)	0.90%

VARIABLE INTEREST ENTITIES ("_8

VARIABLE INTEREST ENTITIES ("VIEs") - Financial Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Balance sheet
Current assets	$ 1,258,506	$ 925,597
Current liabilities	(414,412)	(1,307,221)
Statement of operations
Liquefaction services revenue	267,740	260,273	$ 261,388
Realized and unrealized gain/(loss) on oil and gas derivative instruments	520,997	204,663	(42,561)
Liquefaction services revenue
Statement of operations
Liquefaction services revenue	213,970	221,020	226,061
Variable interest entity, primary beneficiary \| Hilli LLC
Balance sheet
Current assets	105,738	157,643
Non-current assets	1,481,722	1,280,217
Current liabilities	(381,131)	(444,352)
Non-current liabilities	(240,146)	(270,371)
Statement of operations
Realized and unrealized gain/(loss) on oil and gas derivative instruments	520,997	204,663	(42,561)
Statement of cash flows
Net debt repayments	(123,554)	(97,056)	(322,304)
Net debt receipts	20,640	2,848	230,721
Cash dividends paid	(55,169)	(33,136)	(26,072)
Variable interest entity, primary beneficiary \| Golar Gimi
Balance sheet
Current assets	12,460	7,107
Non-current assets	1,195,725	877,835
Current liabilities	(10,666)	(18,127)
Non-current liabilities	(516,298)	(389,244)
Statement of cash flows
Additions to asset under development	267,421	213,481	217,590
Capitalized financing costs	(2,748)	(5,605)	(11,302)
Net debt receipts	125,000	110,000	170,000
Proceeds from subscription of equity interest	39,275	25,403	11,081
Variable interest entity, primary beneficiary \| Liquefaction services revenue \| Hilli LLC
Statement of operations
Liquefaction services revenue	$ 213,970	$ 221,020	$ 226,061

SEGMENT INFORMATION - Narrative

SEGMENT INFORMATION - Narrative (Details)	12 Months Ended
SEGMENT INFORMATION - Narrative (Details)	Dec. 31, 2022 segment operational_flng undergoing_conversion
Segment Reporting Information [Line Items]
Number of reportable segments \| segment	3
Number of operational FLNG \| operational_flng	1
Gimi conversion
Segment Reporting Information [Line Items]
Number of undergoing conversions \| undergoing_conversion	1

SEGMENT INFORMATION - Summary o

SEGMENT INFORMATION - Summary of Reconciliation of Net Income/(Loss) to Adjusted EBITDA (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income/(loss)	$ 939,057	$ 560,615	$ (167,930)
Income taxes	(438)	1,440	579
Income/(loss) before income taxes	938,619	562,055	(167,351)
Depreciation and amortization	51,712	55,362	55,940
Impairment of long-lived assets	76,155	0	0
Unrealized (gain)/loss on oil and gas derivative instruments (note 8)	(520,997)	(204,663)	42,561
Realized and unrealized mark-to-market (gains)/losses on our investment in listed equity securities (note 9)	(400,966)	295,777	0
Other non-operating (income)/losses (note 9)	(11,916)	66,027	(5,682)
Interest income	(12,225)	(128)	(1,479)
Interest expense	19,286	34,486	39,182
(Gains)/losses on derivative instruments (note 10)	(71,497)	(24,348)	52,423
Other financial items, net (note 10)	5,380	(693)	557
Net (income)/loss from equity method investments (note 17)	(19,041)	(1,080)	537
Net loss/(income) from discontinued operations (note 14)	76,450	(625,389)	142,912
Adjusted EBITDA	362,980	182,178	162,139
Oil and gas derivative
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (gain)/loss on oil and gas derivative instruments (note 8)	(288,977)	(179,891)	45,100
Continuing operations
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Income taxes	438	(1,440)	(579)
Depreciation and amortization	51,712	55,362	55,940
Impairment of long-lived assets	76,155	0	0
Realized and unrealized mark-to-market (gains)/losses on our investment in listed equity securities (note 9)	(400,966)	295,777	0
Net (income)/loss from equity method investments (note 17)	$ (19,041)	$ (1,080)	$ 537

SEGMENT INFORMATION - Segment R

SEGMENT INFORMATION - Segment Reporting Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Operations:
Total operating revenues	$ 267,740	$ 260,273	$ 261,388
Vessel operating expenses	72,802	64,366	57,252
Voyage, charterhire and commission expenses	2,444	669	1,544
Administrative (income)/expenses	(38,100)	(35,311)	(34,376)
Other operating losses	(15,417)	0	0
Adjusted EBITDA	362,980	182,178	162,139
Net income/(losses) from equity method investments	19,041	1,080	(537)
Severance costs	500
Balance Sheet:
Total assets	4,279,560	4,948,295
Equity method investments	104,108	52,215	44,385
Capital expenditures (note 18 and 20)	304,193	219,582
Assets held for sale	721	1,697,776
Vessel management fees and other revenues
Statement of Operations:
Total operating revenues	44,085	27,777	20,695
Continuing operations
Statement of Operations:
Net income/(losses) from equity method investments	19,041	1,080	(537)
Balance Sheet:
Total assets	4,278,839	3,250,519
Equity method investments	104,108	52,215
Capital expenditures (note 18 and 20)	304,193	219,582
Operating segments \| Continuing operations
Statement of Operations:
Total operating revenues	267,740	260,273	261,388
Vessel operating expenses	72,802	64,366	(57,252)
Voyage, charterhire and commission expenses	2,444	(669)	1,544
Administrative (income)/expenses	(38,100)
Administrative (income)/expenses		(35,311)	(34,376)
Project development expenses	(8,017)		(8,616)
Project development income/(expenses)		(2,521)
Realized gain on oil and gas derivative instruments (note 8)	232,020	24,772	2,539
Other operating losses	(15,417)
Adjusted EBITDA	362,980	182,178	162,139
Net income/(losses) from equity method investments	24,234	0	0
Operating segments \| FLNG \| FLNG Study
Statement of Operations:
Total operating revenues	900
Operating segments \| FLNG \| Continuing operations
Statement of Operations:
Total operating revenues	214,825	221,020	226,061
Vessel operating expenses	58,583	51,195	(52,104)
Voyage, charterhire and commission expenses	600	(600)	0
Administrative (income)/expenses	22
Administrative (income)/expenses		(241)	(1,672)
Project development expenses	(5,335)		(2,793)
Project development income/(expenses)		(3,171)
Realized gain on oil and gas derivative instruments (note 8)	232,020	24,772	2,539
Other operating losses	(15,417)
Adjusted EBITDA	366,932	190,585	172,031
Net income/(losses) from equity method investments	0	0	0
Balance Sheet:
Total assets	2,815,552	2,314,342
Equity method investments	0	0
Capital expenditures (note 18 and 20)	301,292	219,582
Operating segments \| Corporate and other \| Continuing operations
Statement of Operations:
Total operating revenues	43,230	27,777	20,695
Vessel operating expenses	6,578	12,119	504
Voyage, charterhire and commission expenses	34	166	0
Administrative (income)/expenses	(38,224)
Administrative (income)/expenses		(34,913)	(32,068)
Project development expenses	(2,637)		(5,711)
Project development income/(expenses)		507
Realized gain on oil and gas derivative instruments (note 8)	0	0	0
Other operating losses	0
Adjusted EBITDA	(4,243)	(18,582)	(16,580)
Net income/(losses) from equity method investments	(5,193)	1,080	(537)
Balance Sheet:
Total assets	1,410,587	807,276
Equity method investments	48,669	52,215
Capital expenditures (note 18 and 20)	0	0
Operating segments \| Shipping \| Continuing operations
Statement of Operations:
Total operating revenues	9,685	11,476	14,632
Vessel operating expenses	7,641	1,052	(5,652)
Voyage, charterhire and commission expenses	1,810	(235)	1,544
Administrative (income)/expenses	102
Administrative (income)/expenses		(157)	(636)
Project development expenses	(45)		(112)
Project development income/(expenses)		143
Realized gain on oil and gas derivative instruments (note 8)	0	0	0
Other operating losses	0
Adjusted EBITDA	291	10,175	6,688
Net income/(losses) from equity method investments	24,234	0	$ 0
Balance Sheet:
Total assets	52,700	128,901
Equity method investments	55,439	0
Capital expenditures (note 18 and 20)	$ 2,901	$ 0

SEGMENT INFORMATION - Revenues

SEGMENT INFORMATION - Revenues from External Customers (Details) - Perenco and SNH - Sales revenue, net - Customer concentration risk - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues from external customers:
Concentration risk amount	$ 213,970	$ 221,020	$ 226,061
Concentration risk percentage (in percent)	80%	85%	86%

SEGMENT INFORMATION - Geographi

SEGMENT INFORMATION - Geographic Data (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues from External Customers and Long-Lived Assets [Line Items]
Liquefaction services revenue	$ 267,740	$ 260,273	$ 261,388
Total assets	4,279,560	4,948,295
FLNG \| Cameroon \| Operating segments
Revenues from External Customers and Long-Lived Assets [Line Items]
Total assets	1,559,158	1,408,444	1,264,085
Liquefaction services revenue
Revenues from External Customers and Long-Lived Assets [Line Items]
Liquefaction services revenue	$ 213,970	$ 221,020	$ 226,061

REVENUE - Disaggregation of rev

REVENUE - Disaggregation of revenue (Details) $ in Thousands, t in Millions, ft³ in Billions	1 Months Ended		12 Months Ended
	Jul. 31, 2022 t	Jul. 31, 2021 t	Dec. 31, 2022 USD ($) $ / barrel t	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Mar. 31, 2021 ft³
Disaggregation of Revenue [Line Items]
Total operating revenues			$ 267,740	$ 260,273	$ 261,388
Oil price per barrel (in dollars per barrel) \| $ / barrel			60
Capacity, cubic feet \| ft³						500
Contract with customer, liability, noncurrent			$ (54,018)	(14,515)
Decrease in other cost and expense, operating			15,700
Decrease in revenue, demurrage cost			1,600	0
Decrease in revenue, liquidated damages			600	600
Contract with customer, liability			62,416	18,736	22,856
Hilli LLC
Disaggregation of Revenue [Line Items]
Contract with customer, liability, noncurrent			$ (35,800)
Capacity utilization of Hilli (in tons) \| t	0.2	0.2
Utilization (in tons) \| t			1.4
Hilli LLC \| Maximum
Disaggregation of Revenue [Line Items]
Capacity utilization of Hilli (in tons) \| t	0.4
Golar Tundra
Disaggregation of Revenue [Line Items]
Total operating revenues			$ 14,400
Contract with customer, liability, noncurrent			(7,800)
Contract with customer, liability			4,200
Revenue, remaining performance obligation, amount			4,900
Base tolling fee
Disaggregation of Revenue [Line Items]
Total operating revenues			204,501	204,501	204,501
Liquefaction services revenue
Disaggregation of Revenue [Line Items]
Total operating revenues			213,970	221,020	226,061
Amortization of deferred commissioning period billing			4,120	4,120	4,220
Amortization of Day 1 gains			22,608	9,712	9,950
Overproduction revenue			(20,089)	3,249	7,965
Incremental base tolling fee			5,000	0	0
Other			(2,170)	(562)	(575)
Decrease in revenue from contract with customer			20,100
Vessel management fees and other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues			44,085	27,777	20,695
Management fee revenue			27,916	27,411	20,695
Service revenue			14,423	0	0
Other revenues			1,746	$ 366	$ 0
Sub-leasing income			400
Vessel management fees and other revenues \| FLNG
Disaggregation of Revenue [Line Items]
Other revenues			$ 900

REVENUE - Contract assets and l

REVENUE - Contract assets and liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Aug. 31, 2022
Change In Contract With Customer Liability [Roll Forward]
Contract assets	$ 21,297	$ 21,778
Current contract liabilities	(8,398)	(4,221)
Non-current contract liabilities	(54,018)	(14,515)
Total contract liabilities	(62,416)	(18,736)
Contract with customer, liability, beginning balance	(18,736)	(22,856)
Liability, deferred commission period billing	(62,223)	0
Services revenue recognized during the period	18,543	4,120
Contract with customer, liability, ending balance	$ (62,416)	$ (18,736)
Liquefaction services revenue \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Change In Contract With Customer Liability [Roll Forward]
Reaming contract term (in years)	3 years 6 months
Golar Tundra
Change In Contract With Customer Liability [Roll Forward]
Non-current contract liabilities	$ (7,800)
Total contract liabilities	(4,200)
Services revenue recognized during the period	14,400
Contract with customer, liability, ending balance	(4,200)
Golar Tundra \| Development Agreement
Change In Contract With Customer Liability [Roll Forward]
Current contract liabilities			$ (18,600)
Hilli \| Underutilization liability
Change In Contract With Customer Liability [Roll Forward]
Non-current contract liabilities	(35,800)
Hilli \| Deferred revenue
Change In Contract With Customer Liability [Roll Forward]
Non-current contract liabilities	(10,400)
Golar Artic \| Advance payment liability
Change In Contract With Customer Liability [Roll Forward]
Non-current contract liabilities	$ (7,800)

REALIZED AND UNREALIZED GAIN__3

REALIZED AND UNREALIZED GAIN/(LOSS) ON OIL AND GAS DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain on oil and gas derivative instruments, net	$ 232,020	$ 24,772	$ 2,539
Unrealized gain/(loss) on oil and gas derivative instruments, net	288,977	179,891	(45,100)
Realized and unrealized gain/(loss) on oil and gas derivative instruments	520,997	204,663	(42,561)
Gas
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain/(loss) on derivatives	139,929	0	0
Unrealized gain/(loss) on derivatives	121,959	51,286	0
Oil
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain/(loss) on derivatives	110,696	24,772	2,539
Unrealized gain/(loss) on derivatives	55,315	126,940	(45,100)
Commodity swap
Derivative Instruments, Gain (Loss) [Line Items]
Realized mark-to-market (“MTM”) adjustment on commodity swap derivatives	(18,605)	0	0
Unrealized MTM adjustment for commodity swap derivatives	$ 111,703	$ 1,665	$ 0

OTHER NON-OPERATING INCOME_(L_3

OTHER NON-OPERATING INCOME/(LOSSES) (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2020	Mar. 31, 2019	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Realized and unrealized MTM gains/(losses) on our investment in listed equity securities (note 16)			$ 400,966	$ (295,777)	$ 0
UK tax lease liability (note 29)			7,148	(71,739)	0
Dividend income from our investment in listed equity securities			4,768	5,588	0
Gain on disposal of the LNG Croatia			0	0	5,682
Others			0	124	0
Total other non-operating income/(losses)			412,882	(361,804)	5,682
Unrealized gain (loss)			350,900	295,800
Carrying value of converted vessel, LNG Croatia	$ 658,247		$ 1,152,032	$ 877,838	658,247
New Fortress Energy (NFE)
Investment owned (in shares)			5.3	18.6
Investment owned, shares sold (in shares)			13.3
Proceeds for shares issued			$ 625,600
Fees paid			3,800
Gain on marketable securities			$ 50,100
LNG Croatia Conversion
Contracted revenue, period (in years)		10 years
LNG Croatia
Gain on disposal of long lived asset	5,700
Cash consideration received					193,300
Carrying value of converted vessel, LNG Croatia	$ 187,600				$ 187,600
Minimum \| New Fortress Energy (NFE)
Sale of stock (in USD/NOK per share)			$ 40.80
Maximum \| New Fortress Energy (NFE)
Sale of stock (in USD/NOK per share)			$ 58.29

GAINS_(LOSSES) ON DERIVATIVE _3

GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Gains/(losses) on derivative instruments, net	$ 71,497	$ 24,348	$ (52,423)
Interest rate swap
Derivative Instruments, Gain (Loss) [Line Items]
Gains/(losses) on derivative instruments, net	72,269	27,016	(38,601)
Net interest expense on undesignated IRS derivatives	(772)	(2,908)	(6,215)
Foreign exchange swap
Derivative Instruments, Gain (Loss) [Line Items]
Gains/(losses) on derivative instruments, net	0	240	(2,556)
Equity derivative
Derivative Instruments, Gain (Loss) [Line Items]
Gains/(losses) on derivative instruments, net	$ 0	$ 0	$ (5,051)

GAINS_(LOSSES) ON DERIVATIVE _4

GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET- FINANCIAL ITEMS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Financing arrangement fees and other related costs	$ (9,340)	$ (1,201)	$ (1,409)
Amortization of debt guarantees	2,657	2,569	4,111
Foreign exchange gain/(loss) on operations	1,598	(384)	(3,107)
Other	295	291	152
Other financial items, net	(5,380)	$ 693	$ (557)
Corporate bilateral facility
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Financing arrangement fees and other related costs	(4,900)
7% Unsecured Bonds, Maturing Oct 2025
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Financing arrangement fees and other related costs	(2,300)
Corporate RCF
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Financing arrangement fees and other related costs	$ (1,400)

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	12 Months Ended
INCOME TAXES (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Components of income tax expense:
Current tax expense	$ (520)	$ (1,445)	$ (375)
Deferred tax benefit/(expense)	958	5	(204)
Total income tax benefit/(expense)	$ 438	$ (1,440)	$ (579)

INCOME TAXES - Tax Expense (Ben

INCOME TAXES - Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Statutory tax rate	0%	0%	0%
Deferred tax benefit/(expense)	$ 958	$ 5	$ (204)
Effect of adjustments in respect of current tax in prior periods	346	(232)	40
Effect of taxable income in various countries	(866)	(1,213)	(415)
Total income tax benefit/(expense)	$ 438	$ (1,440)	$ (579)

INCOME TAXES - Narrative (Detai

INCOME TAXES - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Deferred tax liabilities	$ 0.4	$ 0.6

EARNINGS_(LOSS) PER SHARE (Deta

EARNINGS/(LOSS) PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Components of the numerator for the calculation of basic and diluted EPS:
Net loss attributable to Golar LNG Ltd stockholders from continuing operations - basic and diluted, basic	$ 872,429	$ (175,960)	$ (93,991)
Net loss attributable to Golar LNG Ltd stockholders from continuing operations - basic and diluted, diluted	872,429	(175,960)	(93,991)
Net income/(loss) from discontinued operations, basic	(84,656)	589,811	(179,566)
Net income/(loss) from discontinued operations, diluted	$ (84,656)	$ 589,811	$ (179,566)
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Weighted average number of common shares outstanding, basic (in shares)	107,860	109,644	97,554
Dilutive impact of share options and RSUs (in shares)	682	0	0
Weighted average number of common shares outstanding, diluted (in shares)	108,542	109,644	97,554
Earnings Per Share, Basic and Diluted [Abstract]
Basic EPS/(LPS) from continuing operations (in dollars per share)	$ 8.09	$ (1.60)	$ (0.96)
Dilutive EPS/(LPS) from continuing operations (in dollars per share)	8.04	(1.60)	(0.96)
Basic EPS from discontinued operations (in dollars per share)	(0.79)	5.38	(1.84)
Diluted EPS from discontinued operations (in dollars per share)	$ (0.79)	$ 5.38	$ (1.84)

OPERATING LEASES - Minimum Cont

OPERATING LEASES - Minimum Contractual Future Revenues to be Received (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Leases [Abstract]
2023	$ 15,420
Total minimum contractual future revenues	$ 15,420

OPERATING LEASES - Narrative (D

OPERATING LEASES - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Lessor, Lease, Description [Line Items]
Vessels leased to third parties, cost	$ 196,000	$ 196,000
Vessels leased to third parties, accumulated depreciation	152,300	72,800
Operating lease, ROU asset	5,653	10,293
Operating lease, liability, payments, due	$ 5,148	$ 7,900
Weighted average remaining lease term	4 years 9 months 18 days	5 years
Weighted average discount rate, percent	5.50%	5.50%
Total operating revenues	$ 267,740	$ 260,273	$ 261,388
Administrative (income)/expenses	38,100	35,311	34,376
Contract assets	21,297	21,778
Sub-lease agreement
Lessor, Lease, Description [Line Items]
Administrative (income)/expenses	4
Sub-lease agreement \| Minimum
Lessor, Lease, Description [Line Items]
Contract assets	100
Vessel management fees and other revenues
Lessor, Lease, Description [Line Items]
Total operating revenues	44,085	$ 27,777	$ 20,695
Vessel management fees and other revenues \| Sub-lease agreement
Lessor, Lease, Description [Line Items]
Total operating revenues	$ 400

OPERATING LEASES - Operating Le

OPERATING LEASES - Operating Lease Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease income	$ 8,857	$ 11,476	$ 13,887
Variable lease income	828	0	745
Total operating lease income	$ 9,685	$ 11,476	$ 14,632
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration]	Total operating revenues	Total operating revenues

OPERATING LEASES - Operating _2

OPERATING LEASES - Operating Lease Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease cost	$ 4,160	$ 5,899	$ 4,338
Variable lease cost	1,479	1,621	4,000
Total operating lease cost	$ 5,639	$ 7,520	$ 8,338

OPERATING LEASES - Maturity of

OPERATING LEASES - Maturity of Lease Liability (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
2023	$ 1,328
2024	851
2025	1,151
2026	1,088
2027 and thereafter	730
Total minimum lease payments	$ 5,148	$ 7,900

ASSETS AND LIABILITIES HELD F_3

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - Net income/(loss) From Discontinued Operations (Details) - USD ($) $ in Thousands	4 Months Ended	12 Months Ended
	Apr. 15, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations		$ (189,620)	$ 50,448	$ (142,912)
(Loss)/ gain on disposal		113,170	574,941
Net (loss)/income from discontinued operations		(76,450)	625,389	(142,912)
CoolCo
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations		(194,500)	54,534	36,699
(Loss)/ gain on disposal		(10,060)	0	0
Net (loss)/income from discontinued operations		(204,560)	54,534	36,699
TundraCo
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations		4,880	2,806	(3,622)
(Loss)/ gain on disposal		123,230	0
Net (loss)/income from discontinued operations		128,110	2,806	(3,622)
Golar Partners And Hygo Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations	$ (6,892)	0	(6,892)	(175,989)
(Loss)/ gain on disposal	$ 574,939	0	574,941	0
Net (loss)/income from discontinued operations		$ 0	$ 568,049	$ (175,989)

ASSETS AND LIABILITIES HELD F_4

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - Narrative (Details) shares in Millions, $ in Millions				12 Months Ended
	May 31, 2022 USD ($)	Jan. 26, 2022 USD ($) subsidiary	Apr. 15, 2021 USD ($) shares	Dec. 31, 2022 USD ($) segment	Dec. 31, 2021 USD ($)	Aug. 31, 2022 vessel	Jan. 31, 2022 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of reportable segments \| segment				3
Number of vessels sold \| vessel						8
Golar Partners and subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Costs incurred in Hilli operations, capped				$ 20
Discontinued operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of reportable segments \| segment				2
CoolCo \| Loan to related party
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notes receivable, related party				$ 25			$ 25
CoolCo
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investment, ownership percentage				8.30%	0%
The Vessel SPA
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Vessel price		$ 145
The Vessel SPA
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of subsidiaries sold \| subsidiary		9
Number of TFDE vessels disposed \| subsidiary		8
CoolCo
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash sale proceeds				$ 218.2
Discontinued operation, consideration, shares received (in shares) \| shares			12.5
Discontinued operation, consideration, value of shares received				127.1
Golar LNG NB 13 Corporation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage disposed	100%
Consideration received	$ 352.5
Cash sale proceeds	$ 352.5
Golar LNG NB 13 Corporation \| Vessel Management Fees and Other Revenue
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Incurred pool net expenses				0.7
Golar Partners And Hygo Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration received			$ 876.3
Golar Partners And Hygo Energy \| Ship management fees income
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Incurred pool net expenses				9.5	$ 6.9
Golar Partners And Hygo Energy \| Management and administrative services revenue
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Incurred pool net expenses				4.5	3.1
Golar Partners And Hygo Energy \| Charter and debt guarantee fees
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Incurred pool net expenses				1.7	1.4
Golar Partners
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash sale proceeds			80.8
Golar Partners \| Hilli LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Declared distributions by Hilli LLC				29.4	21.2
Hilli costs indemnification				4.1	0.1
Hygo and subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash sale proceeds			$ 50
Discontinued operation, consideration, shares received (in shares) \| shares			18.6
Discontinued operation, consideration, value of shares received			$ 745.4
Hygo and subsidiaries \| Pool income
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Incurred pool net expenses				$ 0.5	$ 2.5

ASSETS AND LIABILITIES HELD F_5

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - CoolCo Results of Operations (Details) - USD ($) $ in Thousands, shares in Millions		12 Months Ended
	Apr. 15, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations		$ (189,620)	$ 50,448	$ (142,912)
(Loss)/ gain on disposal		113,170	574,941
Net (loss)/income from discontinued operations		(76,450)	625,389	(142,912)
CoolCo
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Vessel operating expenses		(8,466)	(49,446)	(46,400)
Voyage, charterhire and commission expenses		(1,229)	(709)	(11,228)
Administrative expenses		1,906	476	(772)
Project development expenses		(62)	(362)	(275)
Depreciation and amortization		(5,807)	(43,497)	(44,437)
Impairment of long-lived assets		(218,349)	0	0
Other operating income		4,374	5,020	3,262
Operating (loss)/income		(188,529)	73,439	64,890
Other non-operating losses		0	(124)	0
Interest income		4	7	67
Interest expense		(4,725)	(18,087)	(26,954)
Other financial items, net		(799)	(401)	(902)
Pre-tax (loss)/income from discontinued operations		(194,049)	54,834	37,101
Income taxes		(451)	(300)	(402)
(Loss)/income from discontinued operations		(194,500)	54,534	36,699
(Loss)/ gain on disposal		(10,060)	0	0
Net (loss)/income from discontinued operations		(204,560)	54,534	36,699
Assets and liabilities disposed		355,400
Cash sale proceeds		218,200
Consideration received (in shares)	12.5
Discontinued operation, consideration, value of shares received		127,100
CoolCo \| Time and voyage charter revenues
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Time and voyage charter revenues		37,289	161,957	164,740
CoolCo \| Vessel management fees and other revenues
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Time and voyage charter revenues		$ 1,815	$ 0	$ 0

ASSETS AND LIABILITIES HELD F_6

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - CoolCo Held for Sale and Discontinued Operations - Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current assets
Total current assets held for sale	$ 721	$ 83,044
Non-current assets
Total non-current assets held for sale	0	1,614,732
Total assets held for sale	721	1,697,776
Current liabilities
Total current liabilities held for sale	(373)	(429,836)
Non-current liabilities
Total non-current liabilities held for sale	0	(450,068)
CoolCo
Current assets
Cash and cash equivalents	369	34,173
Restricted cash and short-term deposits	0	43,311
Trade accounts receivable	16	767
Other current assets	29	1,965
Total current assets held for sale	414	80,216
Non-current assets
Restricted cash	0	780
Vessels and equipment, net	51	1,383,760
Other non-current assets	151	697
Total non-current assets held for sale	202	1,385,237
Total assets held for sale	616	1,465,453
Current liabilities
Current portion of long-term debt and short-term debt	0	(338,501)
Trade accounts payables	(3)	(7,272)
Accrued expenses	(180)	(59,246)
Other current liabilities	(76)	(11,640)
Total current liabilities held for sale	(259)	(416,659)
Non-current liabilities
Long-term debt	0	(292,322)
Other non-current liabilities	(114)	(11,978)
Total non-current liabilities held for sale	(114)	(304,300)
Total liabilities held for sale	$ (373)	$ (720,959)

ASSETS AND LIABILITIES HELD F_7

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - TundraCo Net income (loss) of Equity Method Investments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	May 31, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations	$ (189,620)	$ 50,448	$ (142,912)
Gain on disposal of discontinued operations	113,170	574,941
Net (loss)/income from discontinued operations	(76,450)	625,389	(142,912)
Golar LNG NB 13 Corporation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Vessel operating expenses	(5,119)	(6,511)	(5,274)
Voyage, charterhire and commission expenses	(10,004)	(9,396)	138
Administrative expenses	(16)	(89)	(163)
Depreciation and amortization	(2,955)	(7,092)	(7,546)
Operating (loss)/income	9,682	6,446	(336)
Interest income	0	4	27
Interest expense	(4,649)	(2,589)	(3,219)
Other financial items, net	(153)	(1,055)	(94)
Pre-tax (loss)/income from discontinued operations	4,880	2,806	(3,622)
Income taxes	0	0	0
(Loss)/income from discontinued operations	4,880	2,806	(3,622)
Gain on disposal of discontinued operations	123,230	0	0
Net (loss)/income from discontinued operations	128,110	2,806	(3,622)
Cash sale proceeds				$ 352,500
Net investment value				229,000
Fees incurred in relation to disposal				$ 300
Golar LNG NB 13 Corporation \| Time and voyage charter revenues
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Time and voyage charter revenues	$ 27,776	$ 29,534	$ 12,509

ASSETS AND LIABILITIES HELD F_8

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - TundraCo Balance Sheet of Equity Method Investments (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current assets
Total current assets held for sale	$ 721	$ 83,044
Non-current assets
Non-current assets held for sale	0	1,614,732
Total assets held for sale	721	1,697,776
Current liabilities
Total current liabilities held for sale	(373)	(429,836)
Non-current liabilities
Total non-current liabilities held for sale	0	(450,068)
Golar LNG NB 13 Corporation
Current assets
Cash and cash equivalents	0	2,605
Trade accounts receivable	0	70
Other current assets	105	153
Total current assets held for sale	105	2,828
Non-current assets
Vessels and equipment, net	0	229,495
Non-current assets held for sale	0	229,495
Total assets held for sale	105	232,323
Current liabilities
Current portion of long-term debt and short-term debt	0	(9,911)
Trade accounts payables	0	(204)
Accrued expenses	0	(737)
Other current liabilities	0	(2,325)
Total current liabilities held for sale	0	(13,177)
Non-current liabilities
Long-term debt	0	(145,768)
Total non-current liabilities held for sale	0	(145,768)
Total liabilities held for sale	$ 0	$ (158,945)

ASSETS AND LIABILITIES HELD F_9

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - Golar Partners and Hygo Disposals Net Income of Equity Method Investments for the period ended April 15 (Details) - USD ($) $ in Thousands	4 Months Ended	12 Months Ended
	Apr. 15, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations		$ (189,620)	$ 50,448	$ (142,912)
Gain on disposal of discontinued operations		113,170	574,941
Equity method investments		104,108	52,215	44,385
Realized accumulated comprehensive losses on disposal of investment in affiliate		0	(43,380)	0
Golar Partners
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations	$ 8,116			(136,832)
Golar Partners \| Discontinued operations, disposed of by sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Fees incurred in relation to the release of tax indemnity guarantee liability	2,000
Hygo and subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations	(15,008)			(39,157)
Hygo and subsidiaries \| Discontinued operations, disposed of by sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Realized accumulated comprehensive losses on disposal of investment in affiliate	43,400
Golar Partners And Hygo Energy
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss)/income from discontinued operations	(6,892)	0	(6,892)	(175,989)
Gain on disposal of discontinued operations	574,939	$ 0	$ 574,941	0
Net (loss)/income from discontinued operations	568,047			$ (175,989)
Consideration received	876,300
Golar Partners And Hygo Energy \| Discontinued operations, disposed of by sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investments	257,300
Discontinued operation, transaction cost	$ 2,700

ASSETS AND LIABILITIES HELD _10

ASSETS AND LIABILITIES HELD FOR SALE AND DISCONTINUED OPERATIONS - Golar Partners and Hygo Disposals Summarized Financial Information (Details) - USD ($) $ in Thousands		4 Months Ended	12 Months Ended
	Apr. 15, 2021	Apr. 15, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Investments, ownership percentage			100%
Current assets			$ 1,258,506	$ 925,597
Current liabilities			(414,412)	(1,307,221)
Non-controlling interests			399,950	447,267
Net income/(loss)			$ 939,057	$ 560,615	$ (167,930)
Golar Partners
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets	$ 85,738	$ 85,738			146,821
Non-current assets	1,742,835	1,742,835			1,880,840
Current liabilities	(1,152,473)	(1,152,473)			(832,277)
Non-current liabilities	(17,965)	(17,965)			(570,063)
Non-controlling interests	(82,339)	(82,339)			82,112
Revenue		78,389			284,734
Net income/(loss)		28,952			18,077
Hygo and subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets	97,509	97,509			109,596
Non-current assets	949,265	949,265			917,976
Current liabilities	(144,146)	(144,146)			(97,245)
Non-current liabilities	(461,291)	(461,291)			(453,278)
Non-controlling interests	(15,250)	(15,250)			13,557
Revenue		13,749			47,295
Net income/(loss)		$ (110,735)			$ (61,859)
Hygo and subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net loss, management incentive scheme	$ 83,700

RESTRICTED CASH AND SHORT-TER_3

RESTRICTED CASH AND SHORT-TERM DEPOSITS (Details) $ in Thousands, € in Millions, t in Millions	1 Months Ended	12 Months Ended
	May 31, 2021 USD ($) t	Dec. 31, 2022 USD ($) lease	Dec. 31, 2022 EUR (€)	Nov. 30, 2022 USD ($)	Apr. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)	Nov. 30, 2015 USD ($)
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		$ 134,043				$ 106,073
Less: Amounts included in current restricted cash and short-term deposits		(21,693)				(34,025)
Long-term restricted cash		$ 112,350				72,048
Number of UK leases \| lease		6
Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Letter of credit available to project partner							$ 400,000
LNG production \| t	3.6
Maximum borrowing capacity	$ 100,000
Debt guarantee \| Discontinued operations, disposed of by sale \| Hygo and subsidiaries
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		$ 0		$ 1,500		1,500
Debt guarantee \| Golar Arctic
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		38,822				0
Debt guarantee \| LNG Croatia and NFE's fleet
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		11,504				11,328
Debt guarantee \| LNG Croatia \| Euro member countries, euro
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits \| €			€ 9.3
Debt guarantee \| LNG Croatia \| United States of America, dollars
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		$ 1,300
Term facility		10 years
Debt guarantee \| Hilli
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		$ 60,952				60,720	$ 305,000
Performance guarantee \| Golar Arctic \| Euro member countries, euro
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits \| €			26.9
Performance guarantee \| Golar Arctic \| United States of America, dollars
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		29,800
Variable interest entity, primary beneficiary
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		21,691				16,523
Lease agreements
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		1,074				2
UK tax lease
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		0			$ 16,000	$ 16,000
Advanced Repayment Guarantees \| Golar Arctic \| Euro member countries, euro
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits \| €			8.1
Advanced Repayment Guarantees \| Golar Arctic \| Euro member countries, euro \| Maximum
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits \| €			€ 163.9
Advanced Repayment Guarantees \| Golar Arctic \| United States of America, dollars
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash and short-term deposits		$ 9,000

OTHER CURRENT ASSETS (Details)

OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other non-current assets:
Investment in listed equity securities, fair value	$ 224,788	$ 450,225
Prepaid expenses	2,760	2,692
Other receivables	3,233	2,559
Other current assets	$ 314,542	$ 543,747
Common shares, shares outstanding (in shares)	107,225,832	108,222,604	109,943,594
Dividends receivable	$ 0	$ 600
Golar Arctic Conversion
Other non-current assets:
Other receivables	$ 1,800
New Fortress Energy (NFE)
Other non-current assets:
Common shares, shares outstanding (in shares)	5,300,000	18,600,000
Commodity contract
Other non-current assets:
MTM asset on TTF linked commodity swap derivatives (note 27)	$ 113,368	$ 1,665
Receivable from TTF linked commodity swap derivatives	4,638	0
Commodity contract \| Carrying value
Other non-current assets:
MTM asset on TTF linked commodity swap derivatives (note 27)	73,583	1,753
Money market
Other non-current assets:
Interest receivable	3,617	0
Interest rate swap
Other non-current assets:
Interest receivable	1,923	0
Embedded derivative financial instruments, gas derivative
Other non-current assets:
TTF linked commodity swap collateral	0	6,940
Energy related derivative
Other non-current assets:
Gas derivative instrument (note 27)	$ 0	$ 79,578

EQUITY METHOD INVESTMENTS - Inv

EQUITY METHOD INVESTMENTS - Investments Recorded Using the Equity Method (Details)	Dec. 31, 2022	Dec. 31, 2021	Oct. 01, 2018	Dec. 31, 2011
ECGS
Schedule of Equity Method Investments [Line Items]
Ownership percentage (in percent)	50%	50%		50%
CoolCo
Schedule of Equity Method Investments [Line Items]
Ownership percentage (in percent)	8.30%	0%
Avenir
Schedule of Equity Method Investments [Line Items]
Ownership percentage (in percent)	23.50%	23.50%	25%
Aqualung
Schedule of Equity Method Investments [Line Items]
Ownership percentage (in percent)	4.40%	0%

EQUITY METHOD INVESTMENTS - Car

EQUITY METHOD INVESTMENTS - Carrying Amount (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 104,108	$ 52,215	$ 44,385
CoolCo
Schedule of Equity Method Investments [Line Items]
Equity method investments	55,439	0
Avenir
Schedule of Equity Method Investments [Line Items]
Equity method investments	41,790	47,913
ECGS
Schedule of Equity Method Investments [Line Items]
Equity method investments	4,503	4,302
Aqualung
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 2,376	$ 0

EQUITY METHOD INVESTMENTS - Com

EQUITY METHOD INVESTMENTS - Components (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Balance as of January 1,	$ 52,215	$ 44,385
Additions	129,662	6,750
Net income	19,041	1,080
Guarantee fee	1,708	0
Employee stock compensation	127	0
Share of other comprehensive losses	(797)	0
Proceeds from disposal	(97,848)	0
Balance as of December 31,	$ 104,108	$ 52,215

EQUITY METHOD INVESTMENTS - Add

EQUITY METHOD INVESTMENTS - Additional Information (Details) $ / shares in Units, $ in Thousands			1 Months Ended			12 Months Ended
	Nov. 08, 2018 $ / shares shares	Oct. 01, 2018 USD ($)	Dec. 31, 2022 USD ($) $ / shares	Nov. 30, 2022 USD ($) shares	May 31, 2022 USD ($)	Dec. 31, 2022 USD ($) $ / shares shares	Dec. 31, 2022 kr / shares	Nov. 30, 2022 shares kr / shares	Dec. 31, 2021 USD ($) $ / shares	Dec. 31, 2020 USD ($)	Mar. 31, 2020 USD ($) $ / shares	Dec. 31, 2011 USD ($)	Mar. 31, 2006 $ / shares shares
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 104,108			$ 104,108			$ 52,215	$ 44,385
Common shares, par value (in dollars per share) \| $ / shares			$ 1			$ 1			$ 1
ECGS
Schedule of Equity Method Investments [Line Items]
Common stock purchased (in shares) \| shares													500,000
Common stock purchased, price per share (in dollars per share) \| $ / shares													$ 1
Percentage of voting interest acquired (in percent)			50%			50%							50%
Investee capital share amount called												$ 7,500
Cash paid to maintain equity interest												$ 3,750
CoolCo
Schedule of Equity Method Investments [Line Items]
Sale of NFE common stock (in shares) \| shares				8,000,000
Ownership percentage disposed				11.20%
Ownership percentage after transaction (in percent)			8.30%
Sale of stock (in USD/NOK per share) \| kr / shares								kr 130
Proceeds for shares issued				$ 97,900
Fees paid				1,500
Shares held after transaction (in shares) \| shares								4,500,000
Gain on disposal of interest				$ 400
Share price (in NOK/dollars per share) \| (per share)			$ 11.60			$ 11.60	kr 113.70
Ownership percentage (in percent)			8.30%			8.30%			0%
Equity method investments			$ 55,439			$ 55,439			$ 0
CoolCo \| Private placement
Schedule of Equity Method Investments [Line Items]
Sale of NFE common stock (in shares) \| shares				13,700,000
Sale of stock (in USD/NOK per share) \| kr / shares								kr 130
ECGS
Schedule of Equity Method Investments [Line Items]
Ownership percentage (in percent)			50%			50%			50%			50%
Equity method investments			$ 4,503			$ 4,503			$ 4,302
Avenir
Schedule of Equity Method Investments [Line Items]
Ownership percentage after transaction (in percent)	22.50%
Ownership percentage (in percent)		25%	23.50%			23.50%			23.50%
Equity method investments			$ 41,790			$ 41,790			$ 47,913
Equity method investment, commitment			18,000			18,000
Aggregate cost			$ 42,750			$ 42,750
Avenir \| Stolt-Nielsen Ltd and Höegh LNG Holdings Ltd
Schedule of Equity Method Investments [Line Items]
Investment company, committed capital		$ 182,000
Avenir \| Stolt-Nielsen Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage after transaction (in percent)	45%	50%
Shares subscribed but unissued \| shares	49,500,000
Avenir \| Hoegh LNG Holdings Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage after transaction (in percent)	22.50%	25%
Shares subscribed but unissued \| shares	24,750,000
Avenir \| Private placement
Schedule of Equity Method Investments [Line Items]
Sale of NFE common stock (in shares) \| shares	110,000,000					11,000,000
Equity method investments		$ 24,800
Common shares, par value (in dollars per share) \| $ / shares	$ 1										$ 1
Shares subscribed but unissued \| shares	24,750,000
Equity shortfall notice											$ 45,000
Aqualung
Schedule of Equity Method Investments [Line Items]
Ownership percentage after transaction (in percent)					4.40%
Ownership percentage (in percent)			4.40%			4.40%			0%
Investment company, committed capital					$ 2,400
Equity method investments			$ 2,376			$ 2,376			$ 0
Aqualung \| DK Innovations (US) Inc., Global Ship Lease Inc., MKS Pamp Group Limited and Standard Lithium Ltd.
Schedule of Equity Method Investments [Line Items]
Investment company, committed capital					$ 10,000

EQUITY METHOD INVESTMENTS - Sum

EQUITY METHOD INVESTMENTS - Summarized Financial Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Investments, ownership percentage	100%
Balance Sheet
Current assets	$ 1,258,506	$ 925,597
Total current liabilities	(414,412)	(1,307,221)
Statement of operations
Net income/(loss)	939,057	560,615	$ (167,930)
CoolCo
Balance Sheet
Current assets	145,338	79,293
Non-current assets	1,912,723	1,387,215
Total current liabilities	(278,589)	(417,453)
Non-current liabilities	(1,063,959)	(306,000)
Statement of operations
Revenue	256,434	171,919
Net income/(loss)	110,744	48,368
ECGS
Balance Sheet
Current assets	36,504	41,690
Non-current assets	97	107
Total current liabilities	(25,501)	(31,028)
Non-current liabilities	(931)	(931)
Statement of operations
Revenue	58,680	80,972
Net income/(loss)	713	55
Avenir
Balance Sheet
Current assets	34,028	59,741
Non-current assets	270,177	208,949
Total current liabilities	(69,509)	(38,557)
Non-current liabilities	(92,694)	(66,179)
Statement of operations
Revenue	62,875	16,538
Net income/(loss)	(16,217)	7,119
Aqualung
Balance Sheet
Current assets	5,900	73
Non-current assets	159	0
Total current liabilities	(359)	(70)
Non-current liabilities	0	0
Statement of operations
Revenue	245	0
Net income/(loss)	$ (2,830)	$ (472)

ASSET UNDER DEVELOPMENT - Sched

ASSET UNDER DEVELOPMENT - Schedule of Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Extractive Industries [Roll Forward]
Opening asset under development balance	$ 877,838	$ 658,247
Additions	221,184	178,377
Interest costs capitalized	53,010	41,214
Closing asset under development balance	$ 1,152,032	$ 877,838

ASSET UNDER DEVELOPMENT - Narra

ASSET UNDER DEVELOPMENT - Narrative (Details) $ in Millions	1 Months Ended	12 Months Ended
ASSET UNDER DEVELOPMENT - Narrative (Details) $ in Millions	Oct. 31, 2020	Dec. 31, 2022 USD ($) option	Jun. 30, 2022 USD ($)	Apr. 30, 2019 USD ($)
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Production period		20 years
Number of early termination options \| option		2
Gimi 700 million facility
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Debt instrument, face amount		$ 1,700
Gimi conversion
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Project extension	11 months
Incentive payment agreed upon			$ 50
Gimi conversion \| Gimi 700 million facility
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Debt instrument, face amount				$ 700

ASSET UNDER DEVELOPMENT - Commi

ASSET UNDER DEVELOPMENT - Commitments (Details) - Gimi conversion $ in Thousands	Dec. 31, 2022 USD ($)
Other non-current assets:
2023	$ 385,785
2024	139,669
Contractual obligation, total	$ 525,454

VESSELS AND EQUIPMENT, NET (Det

VESSELS AND EQUIPMENT, NET (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	May 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cost
As of January 1		$ 1,536,736	$ 1,536,759
Additions		77	73
Write-offs			(96)
As of December 31		1,536,813	1,536,736	$ 1,536,759
Depreciation, amortization and impairment
As of January 1		(272,317)	(217,509)
Charge for the year		(51,288)	(54,904)
Impairment loss		(76,155)
Write-offs			96
As of December 31		(399,760)	(272,317)	(217,509)
Net book value as of December 31, 2022		1,137,053	1,264,419
Impairment of long-lived assets		76,155	0	0
License
Depreciation, amortization and impairment
Amortization charge		500	500
Vessels and equipment
Cost
As of January 1		1,374,607	1,374,607
Additions		0	0
Write-offs			0
As of December 31		1,374,607	1,374,607	1,374,607
Depreciation, amortization and impairment
As of January 1		(223,999)	(182,474)
Charge for the year		(39,449)	(41,525)
Impairment loss		(72,607)
Write-offs			0
As of December 31		(336,055)	(223,999)	(182,474)
Net book value as of December 31, 2022		1,038,552	1,150,608
Mooring equipment
Cost
As of January 1		45,771	45,771
Additions		0	0
Write-offs			0
As of December 31		45,771	45,771	45,771
Depreciation, amortization and impairment
As of January 1		(20,363)	(14,820)
Charge for the year		(5,543)	(5,543)
Impairment loss		0
Write-offs			0
As of December 31		(25,906)	(20,363)	(14,820)
Net book value as of December 31, 2022		19,865	25,408
Deferred Drydocking expenditure
Cost
As of January 1		109,094	109,094
Additions		0	0
Write-offs			0
As of December 31		109,094	109,094	109,094
Depreciation, amortization and impairment
As of January 1		(22,767)	(15,948)
Charge for the year		(5,696)	(6,819)
Impairment loss		(3,548)
Write-offs			0
As of December 31		(32,011)	(22,767)	(15,948)
Net book value as of December 31, 2022		77,083	86,327
Office equipment and fittings
Cost
As of January 1		7,264	7,287
Additions		77	73
Write-offs			(96)
As of December 31		7,341	7,264	7,287
Depreciation, amortization and impairment
As of January 1		(5,188)	(4,267)
Charge for the year		(600)	(1,017)
Impairment loss		0
Write-offs			96
As of December 31		(5,788)	(5,188)	$ (4,267)
Net book value as of December 31, 2022		$ 1,553	$ 2,076
Golar Artic
Depreciation, amortization and impairment
Impairment of long-lived assets	$ 76,200

OTHER NON-CURRENT ASSETS (Detai

OTHER NON-CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Components of other non-current assets:
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other non-current assets	Other non-current assets
Operating lease right-of-use-assets	$ 5,653	$ 10,293
Other	32,652	3,673
Other non-current assets	512,039	141,446
Mark II FLNG
Components of other non-current assets:
Other	16,700
Mark II FLNG Long Lead Items
Components of other non-current assets:
Other	10,400
Golar Arctic Conversion
Components of other non-current assets:
Other	2,900
Gas
Components of other non-current assets:
Derivative instrument	196,184	0
Oil
Components of other non-current assets:
Derivative instrument	182,795	127,480
Interest rate swap
Components of other non-current assets:
Derivative instrument	54,970	0
Commodity swap
Components of other non-current assets:
Derivative instrument	$ 39,785	$ 0

DEBT - Schedule of Long-Term De

DEBT - Schedule of Long-Term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Components of long-term debt:
Total debt, net of deferred finance charges	$ (1,189,324)	$ (1,623,300)
Less: Current portion of long-term debt and short-term debt	344,778	703,170
Long-term debt	(844,546)	(920,130)
Repayments of long-term debt:
2023	(344,960)
2024	(104,356)
2025	(277,963)
2026	(93,833)
2027	(58,333)
2028 and thereafter	(330,834)
Total debt (gross)	(1,210,279)	(1,651,507)
Deferred finance charges	20,955	28,207
Total debt, net of deferred financing costs	(1,189,324)	$ (1,623,300)
VIE debt
Repayments of long-term debt:
2023	(337,666)
2024	(60,600)
2025	(60,600)
2026	(35,500)
2027	0
2028 and thereafter	0
Total debt (gross)	(494,366)
Deferred finance charges	256
Total debt, net of deferred financing costs	(494,110)
Golar debt
Repayments of long-term debt:
2023	(7,294)
2024	(43,756)
2025	(217,363)
2026	(58,333)
2027	(58,333)
2028 and thereafter	(330,834)
Total debt (gross)	(715,913)
Deferred finance charges	20,699
Total debt, net of deferred financing costs	$ (695,214)

DEBT - Schedule of Debt (Detail

DEBT - Schedule of Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Subtotal (excluding lessor VIE debt)	$ (715,913)	$ (1,054,227)
Total debt	(1,210,279)	(1,651,507)
Deferred finance charges	20,955	28,207
Total debt, net of deferred financing costs	(1,189,324)	(1,623,300)
Revolving credit facility \| Gimi facility
Debt Instrument [Line Items]
Total debt	(535,000)	(410,000)
Long-term debt \| Unsecured Bonds
Debt Instrument [Line Items]
Total debt	(159,029)	(299,403)
Secured debt \| Golar Arctic facility
Debt Instrument [Line Items]
Total debt	(21,884)	(29,178)
Secured debt \| CSSC VIE debt - FLNG Hilli facility
Debt Instrument [Line Items]
Total debt	(494,366)	(597,280)
Convertible debt \| 2017 Convertible bonds
Debt Instrument [Line Items]
Total debt	$ 0	$ (315,646)

DEBT - Gimi facility, Unsecured

DEBT - Gimi facility, Unsecured Bonds, Golar Arctic Facility, 2017 Convertible Bonds, Corporate RCF and Corporate Bilateral Facility - Narrative (Details) - USD ($)		1 Months Ended					11 Months Ended	12 Months Ended	54 Months Ended	78 Months Ended
	Dec. 31, 2014	Dec. 31, 2022	Feb. 28, 2022	Nov. 30, 2021	Oct. 31, 2021	Oct. 31, 2019	Dec. 15, 2022	Dec. 31, 2022	Oct. 31, 2023	Apr. 30, 2030	Feb. 17, 2017
Gimi 700 million facility
Debt Instrument [Line Items]
Debt instrument, face amount		$ 1,700,000,000						$ 1,700,000,000
Long-term debt \| Gimi 700 million facility
Debt Instrument [Line Items]
Debt instrument, face amount						$ 700,000,000
Balloon payment to be paid						350,000,000
Proceeds from lines of credit								535,000,000
Unsecured debt \| 7% Unsecured Bonds, Maturing Oct 2025
Debt Instrument [Line Items]
Debt instrument, face amount					$ 300,000,000
Coupon rate (in percent)					7%
Redeemed amount		$ 142,200,000						$ 142,200,000
Percentage of nominal amount								100%
Long-term debt, term		4 years						4 years
Unamortized premium		$ 140,700,000						$ 140,700,000
Debt instrument, accrued interest							$ 1,500,000
Gain (loss) on repurchase of debt instrument		2,300,000
Debt instrument, repurchased face amount		$ 140,700,000						$ 140,700,000
Unsecured debt \| 7% Unsecured Bonds, Maturing Oct 2025 \| Put option
Debt Instrument [Line Items]
Percentage of nominal amount								101%
Convertible debt \| 2017 Convertible Bonds
Debt Instrument [Line Items]
Debt instrument, face amount											$ 402,500,000
Coupon rate (in percent)											2.75%
Redeemed amount			$ 321,700,000		$ 85,200,000
Loss on partial redemption of convertible bonds					$ 800,000
Secured debt \| Golar Arctic facility
Debt Instrument [Line Items]
Balloon payment to be paid						$ 9,100,000
Basis spread on variable rate (in percent)	2.25%							2.75%
Maturity period of debt (in days or years)						5 years
Revolving credit facility \| Corporate RCF
Debt Instrument [Line Items]
Debt instrument, face amount				$ 200,000,000
Proceeds from lines of credit			131,000,000
Maturity period of debt (in days or years)				3 years
Corporate bilateral facility \| Corporate bilateral facility
Debt Instrument [Line Items]
Maturity period of debt (in days or years)				7 years
Maximum borrowing capacity			$ 250,000,000
LIBOR \| Corporate RCF
Debt Instrument [Line Items]
Basis spread on variable rate (in percent)				2.80%
LIBOR \| Corporate bilateral facility \| Minimum
Debt Instrument [Line Items]
Basis spread on variable rate (in percent)			4.50%
LIBOR \| Corporate bilateral facility \| Maximum
Debt Instrument [Line Items]
Basis spread on variable rate (in percent)			5.50%
LIBOR \| Long-term debt \| Gimi 700 million facility \| Forecast
Debt Instrument [Line Items]
Basis spread on variable rate (in percent)									4%	3%

DEBT - Lessor VIE Debt (Details

DEBT - Lessor VIE Debt (Details) - USD ($) $ in Thousands	1 Months Ended		12 Months Ended
DEBT - Lessor VIE Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Jul. 31, 2019	Dec. 31, 2022	Dec. 31, 2021	Jun. 30, 2018
Debt Instrument [Line Items]
Loan facility			$ (1,210,279)	$ (1,651,507)
Variable interest entity, primary beneficiary
Debt Instrument [Line Items]
Loan facility			(494,366)
Hilli \| Long-term debt \| Variable interest entity, primary beneficiary
Debt Instrument [Line Items]
Loan facility at inception					$ (840,000)
Loan facility			$ (217,300)
Hilli Lessor VIE \| Long-term debt \| Variable interest entity, primary beneficiary
Debt Instrument [Line Items]
Loan duration (in years)			8 years
Repayments of lines of credit	$ 215,200	$ 150,000
Hilli Lessor VIE \| Short-term Debt \| Variable interest entity, primary beneficiary
Debt Instrument [Line Items]
Loan facility at inception					$ (120,000)
Loan facility			$ (277,100)
Proceeds from lines of credit	$ 223,000	$ 150,000

DEBT - Debt Restrictions Narrat

DEBT - Debt Restrictions Narrative (Details)	Dec. 31, 2022 USD ($)
Debt Disclosure [Abstract]
Restrictive covenants, minimum amount of cash and cash equivalents	$ 50,000,000

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Payables and Accruals [Abstract]
Interest	$ (13,514)	$ (13,767)
Vessel related	(10,795)	(7,925)
Administrative related	(8,039)	(10,122)
Current tax payable	(485)	(1,058)
Accrued expenses	$ (32,833)	$ (32,872)

OTHER CURRENT LIABILITIES (Deta

OTHER CURRENT LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Mark-to-market swaps valuation:
Day 1 gain deferred revenue - current portion	$ (12,783)	$ (38,242)
Deferred revenue	(6,080)	(5,584)
Contract liability for other revenue (note 5)	(4,177)	0
Demurrage cost (note 5)	$ (1,608)	$ 0
Operating lease, liability, current, statement of financial position [Extensible List]	Other current liabilities	Other current liabilities
Current portion of operating lease liability (note 13)	$ (1,328)	$ (3,006)
Liability for UK tax leases (note 29)	0	(71,739)
Other payables	(1,469)	(455)
Other current liabilities	(27,445)	(136,414)
Debt guarantee \| CoolCo
Mark-to-market swaps valuation:
Other payables	(900)
Commodity swap
Mark-to-market swaps valuation:
MTM liability on TTF linked commodity swap derivatives (note 27)	0	(88)
Interest rate swap
Mark-to-market swaps valuation:
MTM liability on TTF linked commodity swap derivatives (note 27)	0	(17,300)
Embedded derivative financial instrument, oil derivative
Mark-to-market swaps valuation:
Day 1 gain deferred revenue - current portion	(10,000)	(10,000)
Embedded derivative financial instruments, gas derivative
Mark-to-market swaps valuation:
Day 1 gain deferred revenue - current portion	$ (2,800)	$ (28,300)

OTHER NON-CURRENT LIABILITIES_2

OTHER NON-CURRENT LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Schedule of Other Long-Term Liabilities [Line Items]
Underutilization liability (note 7)	$ (35,806)	$ 0
Day 1 gain deferred revenue	31,720	34,221
Non-current contract liabilities	$ (54,018)	$ (14,515)
Operating lease, liability, noncurrent, statement of financial position [Extensible List]	Other non-current liabilities	Other non-current liabilities
Pension obligations (note 25)	$ (24,269)	$ (31,357)
Deferred commissioning period revenue	(10,396)	(14,515)
Non-current portion of operating lease liabilities (note 13)	(3,587)	(7,136)
Other payables	(6,834)	(5,730)
Other non-current liabilities	(120,428)	(92,959)
Asset retirement obligation	5,700	5,300
Removal costs capitalized	4,700
Gas
Schedule of Other Long-Term Liabilities [Line Items]
Non-current contract liabilities	(7,200)	0
Oil
Schedule of Other Long-Term Liabilities [Line Items]
Non-current contract liabilities	(24,500)	(34,200)
Golar Arctic
Schedule of Other Long-Term Liabilities [Line Items]
Non-current contract liabilities	$ (7,816)	$ 0

PENSIONS - Narrative (Details)

PENSIONS - Narrative (Details) $ in Thousands	12 Months Ended
PENSIONS - Narrative (Details) $ in Thousands	Dec. 31, 2022 USD ($) defined_benefit_plan	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Pensions:
Defined contribution scheme, charge to net income	$ 1,700	$ 2,200	$ 2,100
Number of defined benefit schemes \| defined_benefit_plan	2
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) Excluding Service Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]	Administrative (income)/expenses, Vessel operating expenses
Net periodic benefit cost	$ 1,682	1,916	1,956
Expected amortization of gain (loss), next fiscal year	(800)	(1,100)
Accumulated benefit obligation	33,900	46,700
Accumulated other comprehensive income (loss), gain (loss), before tax	4,400	10,900
Other comprehensive income, tax on actuarial loss	300	700	$ 600
Employer contributions	2,900	2,900
Administrative Expense And Vessel Operating Expense
Pensions:
Net periodic benefit cost	1,600	1,700
General and Administrative Expense
Pensions:
Net periodic benefit cost	$ 100	$ 200

PENSIONS - Net Periodic Benefit

PENSIONS - Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Components of net periodic benefit cost:
Service cost	$ (75)	$ (120)	$ (155)
Interest cost	(1,087)	(879)	(1,271)
Expected return on plan assets	254	214	318
Recognized actuarial loss	(774)	(1,131)	(848)
Net periodic benefit cost	$ (1,682)	$ (1,916)	$ (1,956)

PENSIONS - Reconciliation of Be

PENSIONS - Reconciliation of Benefit Obligation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of benefit obligation:
Benefit obligation at January 1	$ 47,215	$ 54,122
Service cost	75	120	$ 155
Interest cost	1,087	879	1,271
Actuarial (gain)/loss	(10,106)	(4,081)
Foreign currency exchange rate changes	(1,227)	(120)
Benefit payments	(2,966)	(3,705)
Benefit obligation at December 31	$ 34,078	$ 47,215	$ 54,122

PENSIONS - Reconciliation of Fa

PENSIONS - Reconciliation of Fair Value of Plan Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Reconciliation of fair value of plan assets:
Fair value of plan assets at January 1	$ 15,858	$ 16,864
Actual return on plan assets	(4,392)	(46)
Employer contributions	2,900	2,900
Foreign currency exchange rate changes	(1,591)	(155)
Benefit payments	(2,966)	(3,705)
Fair value of plan assets at December 31	$ 9,809	$ 15,858

PENSIONS - Reconciliation of Fu

PENSIONS - Reconciliation of Funded Status (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of funded status:
Fair value of benefit obligation	$ (34,078)	$ (47,215)	$ (54,122)
Fair value of plan assets	9,809	15,858	$ 16,864
Funded (unfunded) status at end of year	(24,269)	(31,357)
Equity securities
Reconciliation of funded status:
Fair value of plan assets	8,801	15,077
Cash
Reconciliation of funded status:
Fair value of plan assets	1,008	781
UK Scheme
Reconciliation of funded status:
Fair value of benefit obligation	(7,073)	(11,608)
Fair value of plan assets	8,801	15,077
Funded (unfunded) status at end of year	1,728	3,469
Marine Scheme
Reconciliation of funded status:
Fair value of benefit obligation	(27,005)	(35,607)
Fair value of plan assets	1,008	781
Funded (unfunded) status at end of year	$ (25,997)	$ (34,826)

PENSIONS - Asset Allocation (De

PENSIONS - Asset Allocation (Details)	Dec. 31, 2022	Dec. 31, 2021
Marine Scheme
Pensions:
Target allocation	100%	100%
Marine Scheme \| Cash
Pensions:
Target allocation	100%	100%
UK Scheme
Pensions:
Target allocation	100%	100%
UK Scheme \| Equity
Pensions:
Target allocation	100%	100%

PENSIONS - Employer Contributio

PENSIONS - Employer Contributions and Payments (Details) $ in Thousands	Dec. 31, 2022 USD ($)
UK Scheme
Pensions:
Employer contributions	$ 0
Estimated future benefit payments:
2023	340
2024	370
2025	470
2026	390
2027	400
2028 - 2032	2,140
Marine Scheme
Pensions:
Employer contributions	2,900
Estimated future benefit payments:
2023	2,600
2024	2,500
2025	2,400
2026	2,300
2027	2,200
2028 - 2032	$ 9,500

PENSIONS - Assumptions Used (De

PENSIONS - Assumptions Used (Details)	12 Months Ended
PENSIONS - Assumptions Used (Details)	Dec. 31, 2022	Dec. 31, 2021
Weighted average assumptions used in calculating benefit obligation:
Discount rate	4.94%	2.43%
Rate of compensation increase	2.61%	2.70%
Weighted average assumptions used in calculating net periodic benefit cost:
Discount rate	4.93%	2.44%
Expected return on plan assets	1.81%	1.31%
Rate of compensation increase	2.49%	2.75%

SHARE CAPITAL AND SHARE BASED_3

SHARE CAPITAL AND SHARE BASED COMPENSATION - Share Capital (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
SHARE CAPITAL AND SHARE OPTIONS [Abstract]
Common stock, shares authorized (in shares)	150,000,000	150,000,000
Common shares, par value (in dollars per share)	$ 1	$ 1
Common stock, value, authorized	$ 150,000	$ 150,000
Common shares, shares outstanding (in shares)	107,225,832	108,222,604	109,943,594
Common stock, value, issued	$ 107,226	$ 108,223
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares, shares outstanding beginning (in shares)	108,222,604	109,943,594
Common shares, shares issued beginning (in shares)	108,222,604	109,943,594
Repurchase and cancellation of treasury shares (in shares)	(1,189,653)	(1,984,647)
Vesting of share options (in shares)	186,881	263,657
Exercise of share options (in shares)	6,000	0
Common shares, shares outstanding end (in shares)	107,225,832	108,222,604	109,943,594
Common shares, shares issued ending (in shares)	107,225,832	108,222,604	109,943,594
Treasury shares repurchased (in shares)	1,200,000	2,000,000
Repurchase and cancellation of treasury shares	$ 25,477	$ 24,484	$ 16,650
Payments for commissions	20	40
Contributed surplus	$ 200,000	$ 200,000

SHARE CAPITAL AND SHARE BASED_4

SHARE CAPITAL AND SHARE BASED COMPENSATION - Share Options (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	May 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Jul. 31, 2022
Share options:
Options outstanding, granted in period (in shares)		0	750,000
Options, outstanding (in shares)		1,037,000	1,505,000
Weighted average assumptions used:
Expected dividend yield		0%
Outstanding:
Options outstanding, beginning of year (in shares)		1,505,000
Options outstanding, forfeitures in period (in shares)		(334,000)
Exercise of share options (in shares)		6,000	0
Options outstanding, lapsed in period (in shares)		(128,000)
Option outstanding, end of year (in shares)		1,037,000	1,505,000
Weighted average exercise price
Weighted average exercise price, options, outstanding, beginning of year (in dollars per share)		$ 17.65
Weighted average exercise price, options, forfeitures in period (in dollars per share)		21.17
Weighted average exercise price, options, exercises in period (USD per share)		26.90
Weighted average exercise price, options, lapsed in period (in dollars per share)		26.44
Weighted average exercise price, options, outstanding, end of year (in dollars per share)		$ 15.37	$ 17.65
Weighted average remaining contractual term (years)		1 year	1 year 7 months 6 days
Options exercisable, outstanding (in shares)		662,000	755,000	1,717,000
Options exercisable, weighted average exercise price (in dollars per share)		$ 17.87	$ 24.28	$ 24.46
Options exercisable, weighted average remaining contractual term (in years)		9 months 18 days	9 months 18 days	1 year 2 months 12 days
Intrinsic value of share options outstanding and exercisable		$ 7,700	$ 0	$ 0
Total fair value of share options fully vested in the year		1,958	1,595	3,175
Compensation cost recognized in the consolidated statement of income		1,971	1,434	2,274
Share options cost capitalized		$ 0	$ 16	$ 110
Employee \| CoolCo
Weighted average exercise price
Options exercisable, outstanding (in shares)		73,900
LTIP
Share options:
Number of shares authorized for grant (in shares)					138,878
Vesting term		2 years
Term		3 years
Golar scheme
Share options:
Options, outstanding (in shares)		1,000,000	1,500,000	1,800,000
Outstanding:
Options outstanding, beginning of year (in shares)		1,500,000	1,800,000
Option outstanding, end of year (in shares)		1,000,000	1,500,000	1,800,000
Employee stock options
Weighted average assumptions used:
Risk free interest rate	0.20%
Expected volatility of common stock	85%
Expected dividend yield	0%
Expected term of options (in years)	2 years 3 months 18 days
Weighted average exercise price
Total unrecognized compensation cost		$ 700
Weighted average period of recognition for unrecognized compensation cost (in years)		4 months 24 days
Employee stock options \| LTIP
Share options:
Number of shares authorized for grant (in shares)		3,000,000

SHARE CAPITAL AND SHARE BASED_5

SHARE CAPITAL AND SHARE BASED COMPENSATION - Time based RSU's (Details) - Time based restricted stock units - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Share options:
Award vesting period (in years)	3 years
Nonvested, Number of Shares
Non vested RSU's starting balance (in shares)	343,000
Granted during the year (in shares)	97,215	0
Vested during the year (in shares)	(187,000)
Forfeited during the year (in shares)	(35,000)
Non vested RSU's ending balance (in shares)	218,000	343,000
Weighted average grant date fair value per share
Non vested RSU's starting balance (in dollars per share)	$ 9.71
Granted during the year (in dollars per share)	22.52
Vested during the year (in dollars per share)	11.28
Forfeited during the year (in dollars per share)	9.63
Non vested RSU's ending balance (in dollars per share)	$ 14.09	$ 9.71
Weighted average remaining contractual term (years)	1 year 2 months 12 days	1 year 1 month 6 days
Employee \| CoolCo
Nonvested, Number of Shares
Non vested RSU's ending balance (in shares)	32,249

SHARE CAPITAL AND SHARE BASED_6

SHARE CAPITAL AND SHARE BASED COMPENSATION - Performance based RSU's (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Jul. 31, 2022
Weighted average assumptions used:
Expected dividend yield		0%
Implied volatility term (in years)		10 months 24 days
Weighted average grant date fair value per share
Compensation cost recognized in the consolidated statement of income		$ 1,971	$ 1,434	$ 2,274
RSU cost capitalized		$ 0	$ 16	110
LTIP
Share options:
Number of shares authorized for grant (in shares)					138,878
Award vesting period (in years)		3 years
LTIP \| Tranche 1
Share options:
Award vesting right (in percent)		70%
Nonvested RSUs (in shares)		97,215
Nonvested, Number of Shares
Non vested RSU's ending balance (in shares)		97,215
LTIP \| Tranche 2
Share options:
Award vesting right (in percent)		30%
Restricted Stock Units, Time And Performance Based
Weighted average grant date fair value per share
Unrecognized compensation cost		$ 2,600
Weighted average period of recognition for unrecognized compensation cost (in years)		2 years 3 months 18 days
Performance based restricted stock units
Share options:
Number of shares authorized for grant (in shares)	159,430
Nonvested RSUs (in shares)		69,000	28,000
Award vesting period (in years)		3 years
Weighted average assumptions used:
Remaining performance period	2 years 9 months 18 days	1 year 7 months 6 days	1 year 2 months 12 days
Contractual term	3 years
Expected dividend yield	0%
Risk free interest rate	0.42%
Golar volatility	84%
Share price (in NOK/dollars per share)	$ 7.49
Nonvested, Number of Shares
Non vested RSU's starting balance (in shares)		28,000
Granted during the year (in shares)		42,000
Forfeited in period (in shares)		(1,000)
Non vested RSU's ending balance (in shares)		69,000	28,000
Weighted average grant date fair value per share
Non vested RSU's starting balance (in dollars per share)		$ 6.25
Granted during the year (in dollars per share)		22.79
Forfeited during the year (in dollars per share)		22.79
Non vested RSU's ending balance (in dollars per share)		$ 16.05	$ 6.25
Weighted average remaining contractual term (years)	2 years 9 months 18 days	1 year 7 months 6 days	1 year 2 months 12 days
Compensation cost recognized in the consolidated statement of income		$ 1,522	$ 1,774	2,739
RSU cost capitalized		$ 198	$ 322	$ 295
Performance based restricted stock units \| Employee \| CoolCo
Share options:
Nonvested RSUs (in shares)		10,520
Nonvested, Number of Shares
Non vested RSU's ending balance (in shares)		10,520
Performance based restricted stock units \| Minimum
Share options:
Award vesting right (in percent)		0%
Performance based restricted stock units \| Maximum
Share options:
Award vesting right (in percent)		100%

FINANCIAL INSTRUMENTS - Interes

FINANCIAL INSTRUMENTS - Interest Rate Swap Transactions (Details) - Interest rate swap - Cash flow hedging - Designated as hedging instrument - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Notional value	$ 740,000	$ 505,000
Minimum \| LIBOR
Derivative [Line Items]
Fixed interest rates	1.69%	1.69%
Maximum \| LIBOR
Derivative [Line Items]
Fixed interest rates	2.37%	2.37%

FINANCIAL INSTRUMENTS - Narrati

FINANCIAL INSTRUMENTS - Narrative (Details) $ / shares in Units, $ in Thousands, T in Millions	1 Months Ended	12 Months Ended
	Feb. 29, 2020 USD ($) $ / shares shares	Dec. 31, 2022 USD ($) T shares	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 $ / barrel
Derivative [Line Items]
Stock repurchased during period (in shares) \| shares		1,189,653	1,984,647
Cash and cash equivalents		$ 878,838	$ 231,849	$ 85,996	$ 179,699
Equity method investments		104,108	52,215	44,385
Money market funds
Derivative [Line Items]
Cash and cash equivalents		634,200	0
Interest income, interest-earning asset		7,600	0
Golar Partners
Derivative [Line Items]
Purchase of limited partners units \| shares	107,000
Price per share, average (USD per share) \| $ / shares	$ 21.40
CoolCo
Derivative [Line Items]
Equity method investments		55,439	0
Avenir
Derivative [Line Items]
Equity method investments		$ 41,790	$ 47,913
Oil and gas derivative
Derivative [Line Items]
Derivative, floor price (in usd/barrel) \| $ / barrel						60
Derivative, underlying volume (in tons) \| T		1
Equity swap
Derivative [Line Items]
Stock repurchased during period (in shares) \| shares	1,500,000
Price per share, average (USD per share) \| $ / shares	$ 46.91
Derivative, fair value, net	$ 72,700
Derivative liability, fair value of collateral	59,300
Notional value	55,500
Loss on derivative				$ 5,100
Equity swap \| Treasury Shares
Derivative [Line Items]
Notional value	$ 17,200
Maximum \| Oil and gas derivative
Derivative [Line Items]
Derivative, underlying volume (in tons) \| T		0.2

FINANCIAL INSTRUMENTS - Commodi

FINANCIAL INSTRUMENTS - Commodity Price Risk Management (Details)	12 Months Ended
	Dec. 31, 2022 $ / MMBTU tons	Dec. 31, 2021 $ / MMBTU tons
Commodity swap
Derivative [Line Items]
Notional quantity \| tons	4,839,000	1,209,753
Minimum
Derivative [Line Items]
Derivative, forward price	49.50	23.25
Maximum
Derivative [Line Items]
Derivative, forward price	51.20	28

FINANCIAL INSTRUMENTS - Fair Va

FINANCIAL INSTRUMENTS - Fair Value Hierarchy (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Non-Derivatives:
Cash and cash equivalents	$ 878,838	$ 231,849	$ 85,996	$ 179,699
Trade accounts receivable, carrying value	41,545	28,912
Investment in listed equity securities, fair value	224,788	450,225
Collateral amount	1,115,500	1,242,343
Current portion of long-term debt and short-term debt, carrying value	(344,778)	(703,170)
Long-term debt, carrying value	(844,546)	(920,130)
Derivatives:
Deferred finance charges	20,955	28,207
Interest rate swap
Non-Derivatives:
Interest receivable	1,923	0
Commodity contract
Non-Derivatives:
Receivable from TTF linked commodity swap derivatives	4,638	0
Derivatives:
Mark-to-market derivative valuation	113,368	1,665
Derivative liability	0	0
Commodity contract \| Carrying value
Derivatives:
Mark-to-market derivative valuation	73,583	1,753
Level 1 \| Carrying value
Non-Derivatives:
Cash and cash equivalents	878,838	231,849
Restricted cash and short-term deposits, carrying value	134,043	106,073
Trade accounts receivable, carrying value	41,545	28,912
Receivable from TTF linked commodity swap derivatives	4,638	0
Interest receivable	1,923	0
Investment in listed equity securities, carrying value	224,788	449,666
Collateral amount	0	6,940
Trade accounts payable, carrying value	(8,983)	(4,929)
Derivatives:
TTF linked commodity swap collateral	0	6,900
Level 1 \| Fair value
Non-Derivatives:
Cash and cash equivalents, fair value	878,838	231,849
Restricted cash and short-term deposits, fair value	134,043	106,073
Trade accounts receivable, fair value	41,545	28,912
Other receivables, fair value disclosure	4,638	0
Interest receivable, fair value	1,923	0
Investment in listed equity securities, fair value	224,788	449,666
Collateral amount, fair value	0	6,940
Trade accounts payable, fair value	(8,983)	(4,929)
Level 2 \| Carrying value
Non-Derivatives:
Assets held for sale (note 14)	721	1,697,776
Liabilities held for sale (note 14)	(373)	(879,904)
Current portion of long-term debt and short-term debt, carrying value	(344,960)	(388,005)
Current portion of convertible bonds, carrying value	0	(315,646)
Long-term debt, carrying value	(706,290)	(947,855)
Unsecured bonds, carrying value	159,029	0
Level 2 \| Fair value
Non-Derivatives:
Assets held-for-sale, fair value	721	1,697,776
Liabilities Held For Sale, Fair Value	(373)	(879,904)
Current portion of long-term debt and short-term debt, fair value	(344,960)	(388,005)
Current portion of convertible bonds, fair value	0	(316,561)
Long-term debt, fair value	(706,290)	(947,855)
Unsecured bonds, fair value	158,092	0
Level 2 \| Oil and gas derivative \| Carrying value
Derivatives:
Mark-to-market derivative valuation	378,979	207,058
Level 2 \| Oil and gas derivative \| Fair value
Derivatives:
Mark-to-market derivative valuation	378,979	207,058
Level 2 \| Interest rate swap \| Carrying value
Derivatives:
Mark-to-market derivative valuation	54,970	0
Derivative liability	0	(17,300)
Level 2 \| Interest rate swap \| Fair value
Derivatives:
Mark-to-market derivative valuation	54,970	0
Derivative liability	0	(17,300)
Level 2 \| Commodity contract \| Carrying value
Derivatives:
Mark-to-market derivative valuation	113,368	1,753
Derivative liability	0	(88)
Level 2 \| Commodity contract \| Fair value
Derivatives:
Mark-to-market derivative valuation	113,368	1,753
Derivative liability	$ 0	$ (88)

FINANCIAL INSTRUMENTS - Fair _2

FINANCIAL INSTRUMENTS - Fair Values of Derivative Instruments on a Gross Basis (Details) - Commodity contract - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative asset	$ 113,368	$ 1,665
Derivative liability	$ 0	$ 0

FINANCIAL INSTRUMENTS - Offsett

FINANCIAL INSTRUMENTS - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	$ 547,317	$ 208,811
Liabilitiy derivatives, gross amounts not offset in the consolidated balance sheet subject to netting agreements	0	17,388
Commodity contract
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	113,368	1,753
Liabilitiy derivatives, gross amounts not offset in the consolidated balance sheet subject to netting agreements	0	88
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	0	(88)
Mark-to-market derivative valuation	113,368	1,665
Total derivative liabilities
Gross amounts presented in the consolidated balance sheet	0	88
Gross amounts not offset in the consolidated balance sheet subject to netting agreements	0	88
Derivative liability	0	0
Energy related derivative \| Oil
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	182,795	127,480
Energy related derivative \| Natural gas
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	196,184	79,578
Interest rate swap
Total asset derivatives
Gross amounts presented in the consolidated balance sheet	(54,970)	0
Liabilitiy derivatives, gross amounts not offset in the consolidated balance sheet subject to netting agreements	$ 0	$ 17,300

RELATED PARTY TRANSACTIONS - Tr

RELATED PARTY TRANSACTIONS - Transactions and balances with Cool Company Ltd and Subsidiaries (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($) subsidiary	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Jan. 31, 2022 USD ($)
Related Party Transaction [Line Items]
Administrative (income)/expenses	$ 38,100	$ 35,311	$ 34,376
Amount due from (to) related party	$ 3,553	$ 3,306
Golar Ice And Golar Kelvin
Related Party Transaction [Line Items]
Number of disposed subsidiaries agreed to remain as guarantor of payment obligations \| subsidiary	2
Guaranty, lease obligations \| CoolCo
Related Party Transaction [Line Items]
Guaranty liabilities	$ 210,300
CoolCo
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	(486)
Amount due from (to) related party	394
Management and administrative services revenue \| CoolCo
Related Party Transaction [Line Items]
Revenue from related parties	3,124
Ship management fees income \| CoolCo
Related Party Transaction [Line Items]
Revenue from related parties	1,249
Costs and expenses, related party	(5,811)
Ship management fees income \| CoolCo \| NFE's fleet
Related Party Transaction [Line Items]
Administrative (income)/expenses	4,800
Ship management fees income \| CoolCo \| Golar Artic And Golar Tundra
Related Party Transaction [Line Items]
Costs and expenses, related party	(600)
Ship management fees income \| CoolCo \| Hilli
Related Party Transaction [Line Items]
Costs and expenses, related party	(100)
Ship management fees income \| CoolCo \| LNG Croatia and NFE's fleet
Related Party Transaction [Line Items]
Costs and expenses, related party	(5,100)
Debt guarantee compensation \| CoolCo
Related Party Transaction [Line Items]
Compensation amount	837
Commitment fee on revolving credit facility \| CoolCo
Related Party Transaction [Line Items]
Compensation amount	$ 115
Debt Guarantee Percentage \| CoolCo
Related Party Transaction [Line Items]
Related party transaction rate	0.50%
Loan to related party \| CoolCo
Related Party Transaction [Line Items]
Related party transaction rate	5%
Maturity period of debt (in days or years)	2 years
Notes receivable, related party	$ 25,000			$ 25,000
Annual commitment fee	0.50%
Commitment fee on short term loan \| CoolCo
Related Party Transaction [Line Items]
Compensation amount	$ 100

RELATED PARTY TRANSACTIONS - Na

RELATED PARTY TRANSACTIONS - Narrative (Details) $ in Millions	4 Months Ended	12 Months Ended
	Apr. 15, 2021 USD ($)	Dec. 31, 2022 USD ($) vessel	Dec. 31, 2020 USD ($)
Golar Partners
Related Party Transaction [Line Items]
Guarantor obligations, maximum exposure, undiscounted		$ 20
The Cool Pool \| Voyage, charter hire and commission expenses
Related Party Transaction [Line Items]
Operating expenses	$ 2.9		$ 2.1
The Cool Pool \| Net (loss)/income from discontinued operations
Related Party Transaction [Line Items]
Operating expenses		$ 4.8
CoolCo
Related Party Transaction [Line Items]
Number of vessels \| vessel		8
Sublease income		$ 0.4
Employee benefits and share-based compensation		0.1
Related party transaction, expenses from transactions with related party		$ 0.1
Golar Partners
Related Party Transaction [Line Items]
Dividends received	0.5		10.5
Golar Partners \| Disposal costs indemnification
Related Party Transaction [Line Items]
Related party costs	0.1		0.4
Golar Partners \| Hilli LLC
Related Party Transaction [Line Items]
Payments of dividends	$ 7.2		19.4
OneLNG \| Trading balances with affiliates
Related Party Transaction [Line Items]
Impairment of related party transaction, due from (to) related party			$ 0.1

RELATED PARTY TRANSACTIONS - _2

RELATED PARTY TRANSACTIONS - Transactions with existing related parties - Net (expenses)/revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Net income (expense) from transactions with related party	$ 214	$ 1,761	$ 374
Avenir
Related Party Transaction [Line Items]
Net income (expense) from transactions with related party	246	468	980
Magni Partners
Related Party Transaction [Line Items]
Net income (expense) from transactions with related party	(32)	(189)	(606)
ECGS
Related Party Transaction [Line Items]
Net income (expense) from transactions with related party	$ 0	$ 1,482	$ 0

RELATED PARTY TRANSACTIONS - _3

RELATED PARTY TRANSACTIONS - Transactions with existing related parties - Receivables (Details) - USD ($) $ in Thousands	1 Months Ended		12 Months Ended			14 Months Ended
	Oct. 31, 2022	Oct. 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2022
Related Party Transaction [Line Items]
Amount due from (to) related party			$ 3,553	$ 3,306		$ 3,553
Avenir
Related Party Transaction [Line Items]
Amount due from (to) related party			3,472	3,225		3,472
Avenir \| Debt guarantee compensation
Related Party Transaction [Line Items]
Compensation amount			$ 100	500	$ 1,000
Avenir \| Loan to related party
Related Party Transaction [Line Items]
Loan to related party		$ 5,300
Proceeds from short-term credit facility with Golar Partners						1,800
Related party transaction rate			5%
Avenir \| Other
Related Party Transaction [Line Items]
Debt instrument, interest fee receivable			$ 143			143
Interest and commitment fee receivable				28
Magni Partners
Related Party Transaction [Line Items]
Amount due from (to) related party			$ 81	$ 81		$ 81
Avenir LNG \| Loan to related party
Related Party Transaction [Line Items]
Maturity period of debt (in days or years)		1 year
Loans and lease term	3 years

RELATED PARTY TRANSACTIONS - _4

RELATED PARTY TRANSACTIONS - Transactions with former related parties - Net (expenses)/revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	$ 8,140	$ 24,837
Golar Partners
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	3,986	13,521
Hygo and subsidiaries
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	3,631	10,887
Borr Drilling
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	348	384
2020 Bulkers
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	111	45
OneLNG
Related Party Transaction [Line Items]
Net income (expense) from transactions with former related party	$ 64	$ 0

RELATED PARTY TRANSACTIONS - _5

RELATED PARTY TRANSACTIONS - Transactions with former related parties - Receivables (Details) $ in Thousands	Dec. 31, 2021 USD ($)
Related Party Transaction [Line Items]
Receivables from former related parties	$ 178
Borr Drilling
Related Party Transaction [Line Items]
Receivables from former related parties	149
2020 Bulkers
Related Party Transaction [Line Items]
Receivables from former related parties	$ 29

RELATED PARTY TRANSACTIONS - _6

RELATED PARTY TRANSACTIONS - Transactions with Golar Partners and Subsidiaries - Income (Expense) (Details) - Golar Partners - USD ($) $ in Thousands	4 Months Ended	12 Months Ended
	Apr. 15, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	$ 3,986	$ 13,521
Management and administrative services revenue
Related Party Transaction [Line Items]
Revenue from related parties	1,717	7,941
Ship management fees revenue
Related Party Transaction [Line Items]
Revenue from related parties	2,251	5,263
Interest income on short-term loan
Related Party Transaction [Line Items]
Interest income related parties	$ 18	$ 317

RELATED PARTY TRANSACTIONS - _7

RELATED PARTY TRANSACTIONS - Transactions with Hygo and Affiliates - Net Revenues (Details) - Hygo and subsidiaries - USD ($) $ in Thousands	4 Months Ended	12 Months Ended
	Apr. 15, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Net (expenses) income (due to) from related parties	$ 3,631	$ 10,887
Management and administrative services revenue
Related Party Transaction [Line Items]
Revenue from related parties	2,051	5,281
Ship management fees income
Related Party Transaction [Line Items]
Revenue from related parties	904	1,780
Debt guarantee compensation
Related Party Transaction [Line Items]
Related party transaction amount	$ 676	$ 3,826

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - Schedule of assets pledged (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Collateral amount	$ 1,115,500	$ 1,242,343

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - Narrative (Details) $ in Thousands	1 Months Ended	12 Months Ended
	Apr. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2003 tax_lease
Restricted Cash and Cash Equivalents Items [Line Items]
Number of tax leases \| tax_lease					6
Tax settlement with HMRC	$ 66,400
Cash collateral		$ 134,043	$ 106,073
Other operating income
Restricted Cash and Cash Equivalents Items [Line Items]
Amount received in relation to loss of hire insurance claim		4,400	0	$ 0
UK tax lease
Restricted Cash and Cash Equivalents Items [Line Items]
Cash collateral	$ 16,000	0	$ 16,000
MK II FLNG
Restricted Cash and Cash Equivalents Items [Line Items]
Investment company, committed capital		199,200
MK II FLNG \| Maximum
Restricted Cash and Cash Equivalents Items [Line Items]
Investment company, committed capital		328,500
Golar Tundra
Restricted Cash and Cash Equivalents Items [Line Items]
Investment company, committed capital		12,900
Golar Arctic
Restricted Cash and Cash Equivalents Items [Line Items]
Investment company, committed capital		$ 4,800

SUBSEQUENT EVENTS - Narrative (

SUBSEQUENT EVENTS - Narrative (Details) $ in Thousands, shares in Millions	1 Months Ended		2 Months Ended	12 Months Ended
	Feb. 28, 2023 USD ($) m³ shares	Jan. 31, 2023 USD ($) $ / MMBTU	Feb. 28, 2023 USD ($) shares	Dec. 31, 2022 USD ($)	Mar. 31, 2023 USD ($)	Feb. 28, 2023 kr / shares	Jan. 01, 2023	Dec. 31, 2021 USD ($)	Jul. 12, 2018
Subsequent events:
Underutilization liability				$ 35,806				$ 0
New Fortress Energy (NFE)
Subsequent events:
Proceeds for shares issued				$ 625,600
Golar Hilli LLC \| Golar LNG Limited \| Series A Special Units
Subsequent events:
Percentage ownership by wholly owned subsidiary									89.10%
Golar Hilli LLC \| Golar LNG Limited \| Series B Special Units
Subsequent events:
Percentage ownership by wholly owned subsidiary									89.10%
Golar Hilli LLC \| Golar LNG Limited \| Hilli Common Units
Subsequent events:
Percentage ownership by wholly owned subsidiary									44.60%
Subsequent Event
Subsequent events:
Underutilization liability					$ 35,800
Subsequent Event \| Hilli LLC
Subsequent events:
Payments to acquire investments	$ 100,000
Subsequent Event \| Golar Hilli LLC \| Golar LNG Limited \| Series B Special Units
Subsequent events:
Percentage ownership by wholly owned subsidiary							89.10%
Subsequent Event \| Golar Hilli LLC \| Base tolling fees \| Golar LNG Limited \| Hilli Common Units
Subsequent events:
Percentage ownership by wholly owned subsidiary							94.60%
Subsequent Event \| Golar Hilli LLC \| Gas linked tolling fees \| Golar LNG Limited \| Series B Special Units
Subsequent events:
Percentage ownership by wholly owned subsidiary							95%
Subsequent Event \| Golar Hilli LLC \| Gas linked tolling fees \| Golar LNG Limited \| Hilli Common Units
Subsequent events:
Percentage ownership by wholly owned subsidiary							5%
Subsequent Event \| Golar Hilli LLC \| Oil linked tolling fees \| Golar LNG Limited \| Series A Special Units
Subsequent events:
Percentage ownership by wholly owned subsidiary							89.10%
Subsequent Event \| MK II FLNG
Subsequent events:
Vessel size (in cbm) \| m³	148,000
Payments for deposits	$ 5,000
Contractual obligation	$ 78,000		$ 78,000
Subsequent Event \| Hilli LLC
Subsequent events:
Percentage of common stock outstanding	50%
Subsequent Event \| New Fortress Energy (NFE)
Subsequent events:
Sale of NFE common stock (in shares) \| shares			1.2
Proceeds for shares issued			$ 45,600
Subsequent Event \| New Fortress Energy (NFE) \| New Fortress Energy (NFE)
Subsequent events:
Sale of NFE common stock (in shares) \| shares	4.1
Subsequent Event \| Cool Company
Subsequent events:
Sale of NFE common stock (in shares) \| shares	4.5
Proceeds for shares issued	$ 55,800
Sale of stock (in USD/NOK per share) \| kr / shares						kr 130
Subsequent Event \| March-Dec 2023 TTF linked commodity swaps
Subsequent events:
Percentage of unwound instruments		100%
Underlying derivative \| $ / MMBTU		21.80
Gain on derivative (in USD per millions of BTU) \| $ / MMBTU		28.20
Gain on derivative		$ 75,800
Subsequent Event \| Jan-Dec 2024 TTF linked commodity swaps
Subsequent events:
Percentage of unwound instruments		50%
Underlying derivative \| $ / MMBTU		20.55
Gain on derivative (in USD per millions of BTU) \| $ / MMBTU		30.65
Gain on derivative		$ 49,500
Derivative, Gain, Statement of Income or Comprehensive Income [Extensible Enumeration]		Realized and unrealized gain/(loss) on oil and gas derivative instruments

Uncategorized Items - glng-2022

Label	Element	Value
Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ (1,686,000)
Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Contributed Surplus [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	200,000,000
AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(10,834,000)	[1]
Noncontrolling Interest [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	447,267,000
Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	108,223,000
Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	1,932,998,000
Additional Paid-in Capital [Member] \| Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(39,861,000)
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(501,423,000)
Retained Earnings [Member] \| Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 38,175,000

[1]As of December 31, 2022, 2021 and 2020, our accumulated other comprehensive income/(loss) consisted of (i) $5.7 million gain, $5.0 million gain and $3.5 million loss in relation to our pension and post retirement benefit plan, (ii) $0.8 million, $nil and $nil share of equity method investment’s comprehensive losses from continuing operations, and (iii) $nil, $3.1 million and $17.7 million share of equity method investment’s comprehensive loss from discontinued operations, respectively.