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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 20-F
(Mark One)

☐ | REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g) OF THE SECURITIES EXCHANGE ACT OF 1934

OR

☒ | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended |  | December 31, 2021

OR

☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from |  | to |

OR

☐ | SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Date of event requiring this shell company report |

Commission file number | 000-50113 |

Golar LNG Limited
(Exact name of Registrant as specified in its charter)
(Translation of Registrant's name into English)
Bermuda
(Jurisdiction of incorporation or organization)
2nd Floor, S.E. Pearman Building, 9 Par-la-Ville Road, Hamilton HM 11, Bermuda
(Address of principal executive offices)

| Mi Hong Yoon S.E. Pearman Building, 2nd Floor 9 Par-la-Ville Road, Hamilton HM 11, Bermuda Telephone: +1(441 ) 295-4705 |

(Name, Telephone, E-mail and/or Facsimile number and Address of Company Contact Person)
Securities registered or to be registered pursuant to section 12(b) of the Act.

Title of each class | Trading Symbol | Name of each exchange on which registered
Common Shares, par value, $1.00 per share | GLNG | Nasdaq Global Select Market

Securities registered or to be registered pursuant to section 12(g) of the Act.

None
(Title of class)

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act.

None
(Title of class)

Indicate the number of outstanding shares of each of the issuer's classes of capital or common stock as of the close of the period covered by the annual report.

108,222,604 Common Shares, par value $1.00 per share

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes | X | No |

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 of 15(d) of the Securities Exchange Act 1934.

Yes |  | No | X

Note- Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 from their obligations under those Sections.
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes | X | No |

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Yes | X | No |

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one).

Large accelerated filer | X | Accelerated filer |  | Non-accelerated filer |  | Emerging growth company |

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards† provided pursuant to Section 13(a) of the Exchange Act.

† The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.

Yes | X | No |

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP | X | International Financial Reporting Standards as issued by the International Accounting Standards Board |  | Other |

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17 |  | Item 18 |  |  |

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes |  |  | No | X |

(APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PAST FIVE YEARS)
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.

Yes |  | No |

INDEX TO REPORT ON FORM 20-F

PART I |  | PAGE
ITEM 1. | IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS | 1
ITEM 2. | OFFER STATISTICS AND EXPECTED TIMETABLE | 1
ITEM 3. | KEY INFORMATION | 1
ITEM 4. | INFORMATION ON THE COMPANY | 19
ITEM 4A. | UNRESOLVED STAFF COMMENTS | 35
ITEM 5. | OPERATING AND FINANCIAL REVIEW AND PROSPECTS | 35
ITEM 6. | DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES | 52
ITEM 7. | MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS | 57
ITEM 8. | FINANCIAL INFORMATION | 58
ITEM 9. | THE OFFER AND LISTING | 59
ITEM 10. | ADDITIONAL INFORMATION | 59
ITEM 11. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK | 70
ITEM 12. | DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES | 71
PART II |  |
ITEM 13. | DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES | 71
ITEM 14. | MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS | 71
ITEM 15. | CONTROLS AND PROCEDURES | 71
ITEM 16A. | AUDIT COMMITTEE FINANCIAL EXPERT | 72
ITEM 16B. | CODE OF ETHICS | 72
ITEM 16C. | PRINCIPAL ACCOUNTANT FEES AND SERVICES | 72
ITEM 16D. | EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES | 73
ITEM 16E. | PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS | 74
ITEM 16F. | CHANGE IN REGISTRANT'S CERTIFYING ACCOUNTANT | 74
ITEM 16G. | CORPORATE GOVERNANCE | 74
ITEM 16H. | MINE SAFETY DISCLOSURE | 75
PART III |  |
ITEM 17. | FINANCIAL STATEMENTS | 75
ITEM 18. | FINANCIAL STATEMENTS | 75
ITEM 19. | EXHIBITS | 75
SIGNATURES | 80

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
Matters discussed in this report may constitute forward-looking statements. The Private Securities Litigation Reform Act of 1995 provides safe harbor protections for forward-looking statements in order to encourage companies to provide prospective information about their business. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions and other statements, which are other than statements of historical facts.
We desire to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 and are including this cautionary statement in connection with this safe harbor legislation. This report and any other written or oral statements made by us or on our behalf may include forward-looking statements, which reflect our current views with respect to future events and financial performance. When used in this report, the words “believe,” “anticipate,” “intend,” “estimate” “forecast,” “projected” “plan” “potential,” “continue,” “will," “may,” “could,” “should,” “would,” “expect” and similar expressions identify forward-looking statements.
The forward-looking statements in this report are based upon various assumptions, many of which are based, in turn, upon further assumptions, including without limitation, management's examination of historical operating trends, data contained in our records and other data available from third parties. Although we believe that these assumptions were reasonable when made, because these assumptions are inherently subject to significant uncertainties and contingencies which are difficult or impossible to predict and are beyond our control, we cannot assure you that we will achieve or accomplish these expectations, beliefs or projections. As a result, you are cautioned not to rely on any forward-looking statements.
In addition to these important factors and matters discussed elsewhere herein, important factors that, in our view, could cause actual results to differ materially from those discussed in the forward-looking statements include among other things:
•our inability and that of our counterparty to meet our respective obligations under the Lease and Operate Agreement entered into in connection with the BP Greater Tortue / Ahmeyim Project (“Gimi GTA Project”);
•continuing uncertainty resulting from potential future claims from our counterparties of purported force majeure (“FM”) under contractual arrangements, including but not limited to our construction projects (including the Gimi GTA Project) and other contracts to which we are a party;
•claims made or losses incurred in connection with our continuing obligations with regard to Hygo Energy Transition Ltd. (“Hygo”) and Golar LNG Partners LP (“Golar Partners”);
•the ability of Hygo, Golar Partners and New Fortress Energy Inc. (“NFE”) to meet their respective obligations to us, including indemnification obligations;
•changes to rules and regulations applicable to liquefied natural gas (“LNG”) carriers, floating storage and regasification units (“FSRUs”), floating liquefaction natural gas vessels (“FLNGs”) or other parts of the LNG supply chain;
•changes in our ability to retrofit vessels as FSRUs or FLNGs and in our ability to obtain financing for such conversions on acceptable terms or at all;
•changes in our ability to obtain additional financing on acceptable terms or at all;
•the length and severity of outbreaks of pandemics, including the worldwide outbreak of the novel coronavirus (“COVID-19”) and its impact on demand for LNG and natural gas, the timing of completion of our conversion projects, the operations of our charterers, our global operations and our business in general;
•failure of our contract counterparties to comply with their agreements with us or other key project stakeholders;
•changes in LNG carrier, FSRU, or FLNG charter rates, vessel values or technological advancements;
•our ability to close potential future sales of additional equity interests in our vessels, including the Hilli and Gimi or to monetize our interest in NFE on a timely basis or at all;
•our ability to contract the full utilization of the Hilli or other vessels;
•changes in the supply of or demand for LNG or LNG carried by sea and for LNG carriers, FSRUs or FLNGs;
•a material decline or prolonged weakness in rates for LNG carriers, FSRUs or FLNGs;
•changes in the performance of the pool in which certain of our vessels operate;
•changes in trading patterns that affect the opportunities for the profitable operation of LNG carriers, FSRUs or FLNGs;
•continuing volatility of commodity prices;
•changes in the supply of or demand for natural gas generally or in particular regions;

•changes in our relationships with our counterparties, including our major chartering parties;
•changes in our relationship with our affiliates and the sustainability of any distributions they pay us;
•changes in general domestic and international political conditions, particularly where we operate;
•changes in the availability of vessels to purchase and in the time it takes to build new vessels;
•our inability to achieve successful utilization of our fleet or our inability to expand beyond the carriage of LNG and provision of FSRU and FLNGs, particularly through our innovative FLNG strategy;
•actions taken by regulatory authorities that may prohibit the access of LNG carriers, FSRUs and FLNGs to various ports;
•increases in costs, including, among other things, wages, insurance, provisions, repairs and maintenance; and
•other factors listed from time to time in registration statements, reports or other materials that we have filed with or furnished to the Securities and Exchange Commission, or the Commission, including our most recent annual report on Form 20-F.
Please see our Risk Factors in Item 3 of this report for a more complete discussion of these and other risks and uncertainties. We caution readers of this report not to place undue reliance on these forward-looking statements, which speak only as of their dates. These forward-looking statements are not guarantees of our future performance, and actual results and future developments may vary materially from those projected in the forward-looking statements.We undertake no obligation to publicly update or revise any forward-looking statements, except as required by law. If one or more forward-looking statements are updated, no inference should be drawn that additional updates will be made.

PART I
ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISORS
Not applicable.
ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE
Not applicable.
ITEM 3. KEY INFORMATION
Throughout this report, unless the context indicates otherwise, the “Company”, “Golar”, “Golar LNG”, “we”, “us”, and “our” all refer to Golar LNG Limited or any one or more of its consolidated subsidiaries, including Golar Management Limited, or Golar Management, or to all such entities. References to “Golar Partners” or the “Partnership” refer, depending on the context, to our former affiliate Golar LNG Partners LP (previously listed on Nasdaq: GMLP) and to any one or more of its subsidiaries. References to “Hygo” refer to our former affiliate Hygo Energy Transition Ltd (formerly known as Golar Power Ltd) and to any one or more of its subsidiaries. References to “OneLNG” refer to our former joint venture OneLNG S.A and to any one or more of its subsidiaries. References to “Avenir” refer to our affiliate Avenir LNG Limited (Norwegian OTC: AVENIR) and to any one or more of its subsidiaries. References to “NFE” refer to New Fortress Energy Inc. (Nasdaq: NFE), the third-party purchaser of Golar Partners and Hygo, which acquisition closed on April 15, 2021. References to “Cool Co” refer to Cool Company Ltd (Euronext Growth: COOL) and to any one or more of its subsidiaries. Unless otherwise indicated, all references to “USD” and “$” in this report are to U.S. dollars.
A. Reserved
B. Capitalization and Indebtedness
Not applicable.
C. Reasons for the Offer and Use of Proceeds
Not applicable.
D. Risk Factors
The risk factors summarized and detailed below could materially and adversely affect our business, our financial condition, our operating results of operations and the trading price of our common shares. We have categorized the risks we face based on whether they arise from our business activities or from the industry in which we operate and listed these based on management’s assessment of priority. Where relevant, we have grouped together related risks into the following categories:
◦Risks related to our FLNG project
■Delays and costs associated with renegotiation of our conversion contracts and capital expenditure commitments with Keppel Shipyard Limited (“Keppel”) could adversely affect our earnings, cash flows and financial position; and
■Given the sophisticated nature of FLNG conversions, we are reliant on a limited number of contractors with relevant specialized experience.
◦Risks related to our revenues
■Our operating revenue is dependent on a high customer concentration which a loss of any of our customers could have an adverse effect on our earnings and cashflows;
■Golar Hilli LLC may not result in anticipated profitability or generate sufficient cash flow to justify our investment;
■We cannot guarantee that full utilization of the full capacity of Hilli will occur or if achieved, continues; and
■We are subject to certain risks with respect to our contractual counterparties, and failure of such counterparties to meet their obligations could cause us to suffer losses or otherwise adversely affect our business.
1

◦Risks related to our investments
■Exposure to price volatility of our investment in listed equity securities could adversely affect our financial results;
■Our equity investment in Avenir may not result in anticipated profitability to justify our investment; and
■Our equity investment in Cool Co is subject to certain risks related to the LNG spot market.
◦Risks related to the financing of our business
■We may not be able to obtain new financings, to meet our obligations as they fall due or to fund our growth or our future capital expenditures, which could negatively impact our results of operations, financial condition and ability to pay dividends;
■We guarantee certain indebtedness of our affiliates and external parties. If certain of our affiliates and/or external parties are unable to service their debt requirements or comply with certain provisions contained in their loan agreements, this may have a material adverse effect on us;
■Most of our financing agreements are secured by our vessels and contain operating and financial restrictions and other covenants that may restrict our business, financing activities and ability to make cash distributions to our shareholders;
■NFE has agreed to indemnify us pursuant to the Golar Partners and Hygo Omnibus Agreements. The inability of NFE to satisfy its indemnity obligations to us could have a material adverse effect on our financial condition and results of operations;
■If the Hilli letter of credit (the “LC”) is not extended, the earnings and financial condition of Golar Hilli Corp. (“Hilli Corp”) could suffer;
■We are exposed to volatility in the London Interbank Offered Rate (“LIBOR”), and the derivative contracts we have entered into to hedge our exposure to fluctuations in interest rates could result in higher than market interest rates and charges against our income;
■Servicing our debt agreements substantially limits our funds available for other purposes and our operational flexibility; and
■Our consolidated lessor variable interest entities (“VIEs”) may enter into different financing arrangements, which could affect our financial results.
◦Risks related to our operations
■A cyber-attack could materially disrupt our business;
■A substantial increase in operating costs could have a material adverse effect on our financial performance;
■Marine transportation and oil production are inherently risky, and our operations face several industry risks and events which could cause damage or loss of a vessel, loss of life or environmental consequences that could harm our reputation and ongoing business operations;
■Failure to comply with the U.S. Foreign Corrupt Practices Act, the UK Bribery Act and other anti-bribery legislation in other jurisdictions could result in fines, criminal penalties, contract terminations and an adverse effect on our business;
■Vessel values may fluctuate substantially and, if these values are lower at a time when we are attempting to dispose of vessels, we may incur a loss;
■We will have to make additional contributions to our pension scheme because it is underfunded;
■We are exposed to U.S. dollar and foreign currency fluctuations and devaluations that could harm our reported revenue and results of operations;
■We may be unable to attract and retain key personnel, which may negatively impact the effectiveness of our management and our results of operations; and
■We may be subject to litigation that, if not resolved in our favor and not sufficiently insured against, could have a material adverse effect on us.
◦Risks related to our industry
■Our results of operations and financial condition depend on demand for LNG, LNG carriers, FSRUs and FLNGs;
■Maritime claimants could arrest our vessels, which could interrupt our cash flow;
■Political, governmental and economic instability and sanctions or embargoes imposed by the U.S. or other governmental authorities could adversely affect our business;
■Our operations are subject to extensive and changing laws, regulation and reporting requirement, which may have an adverse effect on our business;
■Climate change and greenhouse gas restrictions may adversely impact our operations and markets; and
2

■Increasing scrutiny and changing expectations from investors, lenders and other market participants with respect to our Environmental, Social and Governance (“ESG”) policies may impose additional costs on us or expose us to additional risks.
◦Risks related to our common shares
■The declaration and payment of dividends is at the discretion of our board of directors;
■If we fail to meet the expectations of analysts or investors, our share price could decline substantially;
■Our common share price may be highly volatile and future sales of our common shares could cause the market price of our common shares to decline and could lead to a loss of all or part of a shareholder's investment;
■We may issue additional common shares or other equity securities without our shareholders’ approval, which would dilute their ownership interests and may depress the market price of our common shares;
■Because we are a Bermuda corporation, our shareholders may have less recourse against us or our directors than shareholders of a U.S. company have against the directors of that U.S. company; and
■Because our offices and most of our assets are outside the U.S., our shareholders may not be able to bring a suit against us, or enforce a judgment obtained against us in the U.S..
◦Risks related to tax
■As a Bermuda exempted company incorporated under Bermuda law with subsidiaries in the Marshall Islands and other offshore jurisdiction, our operations may be subject to economic substance requirements;
■A change in tax laws in any country in which we operate could adversely affect us;
■We could be treated as or become a passive foreign investment company (“PFIC”), which could have adverse U.S. federal income tax consequences to U.S. shareholders;
■We may have to pay tax on U.S. source income, which would reduce our earnings; and
■We may become subject to taxation in Bermuda which would negatively affect our results.
Risks related to our FLNG project
•Delays and costs associated with renegotiation of our conversion contracts and capital expenditure commitments with Keppel could adversely affect our earnings, cash flows and financial position.
In February 2019, we entered into a 20-year Lease and Operate Agreement (the “LOA”) with BP Mauritania Investments Ltd (“BP”) for the charter of the FLNG unit, the Gimi, to service the Gimi GTA Project, which was expected to commence operations under the LOA in 2022. In April 2020, we announced the receipt of a written notification of a FM claim from BP that due to the global outbreak of COVID-19, it was unable to be ready to receive the Gimi in 2022, instead delaying acceptance by 11 months. There is currently no FM, however, we cannot guarantee that there will not be further delays on the Gimi GTA Project.
The LOA further provides both parties with the right to suspend or terminate the agreement under certain circumstances after performance has begun, including as a result of a prolonged FM event. Should we be unable to meet our obligations under the LOA in a manner that gives rise to a right to terminate the agreement by BP, we could be obligated to pay substantial damages to BP which would have a negative impact on our earnings, cash flow and financial condition and could make it difficult to induce counterparties to contract with us for future FLNG conversions.
The $700 million debt facility agreement that we entered into in October 2019 to finance the Gimi conversion was expected to be drawn down in line with our contractual capital expenditure requirements. Changes to the overall Gimi project budget following the agreed revised project schedule with BP was minimal. However, we cannot guarantee that there will not be further delays on the cash inflows from the $700 million debt facility, which could result to delayed vessel delivery and the related commencement of operations.
3

•Given the sophisticated nature of FLNG conversions, we are reliant on a limited number of contractors with relevant specialized experience.
The highly technical work related to FLNG conversions can only be performed by a limited number of contractors, and due to the new nature of the technology, only a very limited number of contractors have relevant experience with FLNG conversions. Accordingly, a change of contractors for any reason would likely result in higher costs and a significant delay to our delivery schedules. In addition, given the novelty of our FLNG conversion projects, the completion of retrofitting our vessels as FLNG vessels could be subject to risks of significant cost overruns. If the shipyard is unable to deliver any converted FLNG vessel on time, we might be unable to perform our obligations under the related charter terms.
Furthermore, if any future FLNG vessels, once converted, are not able to meet certain performance requirements or perform as intended, we may have to accept reduced charter rates or we may not be able to charter the converted FLNG vessel at all. Either of these possibilities would have a negative impact, which could be significant, on our cash flows and earnings.
Risks related to our revenues
•Our operating revenue is dependent on a high customer concentration wherein a loss of any of our customers could have an adverse effect on our earnings and cashflows.
On January 26, 2022, Golar and Cool Co entered into a share purchase agreement (the “Vessel SPA”) under which Cool Co acquired eight modern Tri-Fuel Diesel Electric (“TFDE”) LNG vessels, namely the Golar Seal, Golar Crystal, Golar Bear, Golar Frost, Golar Glacier, Golar Snow, Golar Kelvin, Golar Ice and Cool Pool Limited, the fleet's commercial management company (the “Disposal Group”), from Golar. Following the completion of the transactions contemplated under Vessel SPA, our future revenues are now derived from a limited number of customers. The loss of a key customer or a substantial decline in the amount of services requested by a key customer, or the inability of a customer to pay for our services, could have a material adverse effect on our earnings and financial condition. We could lose a customer or the benefits of a contract if:
•the customer fails to make payments because of its financial inability, disagreements with us or otherwise;
•we breach the relevant contract and the customer exercises certain rights to terminate the contract;
•the customer terminates the contract because we fail to deliver the vessel or service within a fixed period of time, the vessel is lost or damaged beyond repair or prolonged periods of off-hire, or we default under the contract;
•the customer terminates the contract due to prolonged FM affecting the customer, including damage to or destruction of relevant facilities, war or geopolitical unrest preventing us from performing services for that customer; or
•the customer becomes subject to sanction laws which directly or indirectly prohibit our ability to lawfully charter our vessel to such customer.
If we lose a key customer or if a customer exercises its right to terminate the charter, we may be unable to acquire an adequate replacement which could have a material adverse effect on our earnings and financial condition.
•Golar Hilli LLC may not result in anticipated profitability or generate sufficient cash flow to justify our investment.
In July 2018, we, Keppel and Black & Veatch Corporation (“B&V”) completed the sale of 50% of the common units in Golar Hilli LLC (“Hilli LLC”), the disponent owner of the Hilli, to Golar Partners. However, we still hold a significant portion of the outstanding ownership interests in Hilli LLC. The retained interests expose us to risks that we may:
•fail to obtain the benefits of the Liquefication Tolling Agreement (the “LTA”) if Perenco Cameroon S.A. (“Perenco”) and Société Nationale des Hydrocarbures (“SNH”) (together the “Customer”) exercises certain rights to terminate the charter upon the occurrence of specified events of default;
•fail to obtain the benefits of the LTA if the Customer fails to make payments under the LTA because of its financial inability, disagreements with us or otherwise;
•incur or assume unanticipated liabilities, losses or costs;
•be required to pay damages to the Customer or suffer a reduction in the tolling fee in the event that the Hilli fails to perform to certain specifications;
•incur other significant charges, such as asset devaluation or restructuring charges; or
•be unable to re-charter the Hilli on another long-term charter at the end of the LTA.
4

•We cannot guarantee that full utilization of the full capacity of Hilli will occur or, if achieved, continues.
In July 2021, we signed an agreement with the Customer to increase the utilization of Hilli by 0.2 million tons of LNG, commencing in January 2022, from base capacity of 1.2 million tons. The Customer was also granted an option to increase capacity utilization of Hilli by up to 0.4 million tons of LNG per year from January 2023 through to the end of the current contract term in 2026, which must be declared by the Customer in July 2022. The remaining capacity of the Hilli is not yet contracted.
Even if we were able to contract for utilization of the full capacity of the Hilli, we cannot guarantee that the full utilization would continue for any extended period. If we are unable to achieve utilization of full capacity, or to maintain utilization of full capacity in the future, such inability could have a significant effect on our earnings and financial condition.
•We are subject to certain risks with respect to our contractual counterparties, and failure of such counterparties to meet their obligations could cause us to suffer losses or otherwise adversely affect our business.
We have entered into agreements for the provision of certain technical, crew, commercial, corporate secretarial and transition services and have subcontracted the provision of certain services to external parties. Such agreements subject us to subcontractor counterparty risks. The ability of each of our subcontractor counterparty to perform its obligations under a contract with us will depend on a number of factors that are beyond our control and may include, among other things, general economic conditions, the overall financial condition of our subcontractor counterparty, the condition of the maritime and offshore industries and work stoppages or other labor disturbances. Should our subcontractor counterparty fail to honor its obligations under agreements with us, we could sustain significant losses, which could have a material adverse effect on our business, reputation, financial condition, results of operations and cash flow.
Risks related to our investments
•Exposure to price volatility of our investment in listed equity securities could adversely affect our financial results.
Upon completion of the disposal of our equity investment in Hygo, we received 18.6 million shares of NFE Class A common stock (“NFE common stock”) and $50.0 million in cash as purchase considerations. Should the price of our NFE common stock decline materially from the share price at closing of the Hygo merger, our cash flows, financial condition and results of operations could be adversely affected.
•Our equity investment in Avenir may not result in anticipated profitability to justify our investment.
As of December 31, 2021, we invested $42.8 million in Avenir, a joint venture with Stolt-Nielsen Ltd (“Stolt Nielsen”) (an entity affiliated with our director Niels Stolt Nielsen) and Höegh LNG Holdings Ltd (“Höegh”) for the pursuit of opportunities in small-scale LNG. The value of our investment and the income generated from our investment are subject to a variety of risks, including, among others, the inability of the joint venture partners to successfully work together in the shared management of Avenir, inability of Avenir to identify and enter into appropriate projects, inability of Avenir to obtain sufficient financing for any project it identifies, failure of small-scale LNG projects that Avenir has invested in, and other industry, regulatory, economic and political risks impacting Avenir's operations.
•Our equity investment in Cool Co is subject to certain risks related to the LNG spot market.
On the completion of the transactions contemplated under the Cool Co Vessel SPA, we kept a 31.3% shareholding in Cool Co. Given the limited operating history of Cool Co, which may not be sufficient for a potential charterers to evaluate the viability of the company's business, it may be difficult for Cool Co to induce new customers. If Cool Co is not able to compete successfully and win new contracts, our earnings through our equity pick up of the results of Cool Co, could be adversely affected. A sustained decline in charter or spot rates or a failure by Cool Co to successfully charter its participating vessels could have a material adverse effect on our results of operations and Cool Co's ability to meet its financing obligations.
5

Risks related to the financing of our business
•We may not be able to obtain new financing, to meet our obligations as they fall due or to fund our growth or our future capital expenditures, which could negatively impact our results of operations, financial condition and ability to pay dividends.
In order to fund future projects, increased working capital levels or other capital expenditures, we may be required to use cash from operations, incur additional borrowings or raise capital through the sale of debt or additional equity securities. Our ability to do so may be limited by our financial condition at the time of such financing or offering, as well as by adverse market conditions resulting from, among other things, general economic conditions and contingencies and uncertainties that are beyond our control. Our failure to obtain funds for future capital expenditures could impact our results of operations, financial condition and our ability to pay dividends. Furthermore, our ability to access capital, the overall economic conditions and our ability to secure charters on a timely basis could limit our ability to fund our growth plans and capital expenditures. If we are successful in issuing equity in order to raise capital, the issuance of additional equity securities would dilute shareholders' equity interest in us and reduce any pro rata dividend payments without a commensurate increase in cash allocated to dividends, if any. Even if we are successful in obtaining bank financing, paying debt service would limit cash available for working capital and increasing our indebtedness could have a material adverse effect on our business, results of operations, cash flows, financial condition and ability to pay dividends.
As a result of concerns about the stability of financial markets generally, and the solvency of counterparties, the availability and cost of obtaining money from the public and private equity and debt markets has become more difficult. Many lenders have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at all or on terms similar to current debt, and reduced, and in some cases ceased, to provide funding to borrowers and other market participants, including equity and debt investors, and some have been unwilling to invest on attractive terms or even at all. Due to these factors, we cannot be certain that financing will be available if needed and to the extent required, or that we will be able to refinance our existing and future credit facilities, on acceptable terms or at all.
•We guarantee certain indebtedness of our affiliates and external parties. If certain of our affiliates and/or external parties are unable to service their debt requirements or comply with certain provisions contained in their loan agreements, this may have a material adverse effect on us.
We entered into certain agreements to provide stand-ready guarantees to certain banks in connection with, commercial bank indebtedness, charter agreements and certain taxes losses, claims, damages or liabilities imposed by governmental authorities of our affiliates and external parties, including Golar Partners, Hygo and Cool Co. Failure by any of our affiliates and/or external parties to service their debt requirements and comply with any provisions contained in their loan agreements or the charter agreements, including paying scheduled installments and complying with certain financial covenants, may lead to an event of default under the related loan or charter agreements. In such case, we would need to satisfy the obligations or indemnify the losses of the respective affiliate and/or external party. Additionally, if a default occurs under the debt agreements of our affiliated companies and/or external parties, the lenders could accelerate the outstanding borrowings and declare all amounts outstanding due and payable. In this case, if such entities are unable to obtain a waiver or an amendment to the applicable provisions of the debt agreements, or do not have enough cash on hand to repay the outstanding borrowings, the lenders may, among other things, foreclose their liens on the respective assets, or seek repayment of the loan from such entities or from us under the guarantee.
In addition, certain of our debt agreements contain cross-default provisions that may be triggered if the entities described above default under the terms of certain of their debt agreements. In the event of a default by such entities and the refusal of a lender or lessor to grant or extend a waiver, as applicable, the lenders under certain of our debt agreements could determine that we are in default under those debt agreements even if the lenders have waived covenant defaults of such entities under the respective agreements. Such cross-defaults could result in the acceleration of the maturity of the debt under our agreements and our lenders may foreclose upon any collateral securing that debt, including our vessels units and other assets, even if such default was subsequently cured. In the event of such acceleration and foreclosure, we may not have sufficient funds or other assets to satisfy all of our obligations. Further, such acceleration and foreclosure and the results thereof may reduce our ability to obtain future credit from certain lenders.
The occurrence of any of the events described above would have a material adverse effect on our business, results of operations and financial condition, would significantly reduce our ability or make us unable to pay dividends to our shareholders for so long as such default is continuing, and may impair our ability to continue as a going concern.
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•Most of our financing agreements are secured by our vessels and contain operating and financial restrictions and other covenants that may restrict our business, financing activities and ability to make cash distributions to our shareholders.
Most of our obligations are secured by certain of our vessels and guaranteed by our subsidiaries holding the interests in our vessels. Our loan agreements impose, and future financial obligations may impose, operating and financial restrictions on us. These restrictions may require the consent of our lenders, or may prevent or otherwise limit our ability to, among other things: merge into, or consolidate with, any other entity or sell, or otherwise dispose of, all or substantially all of our assets; make or pay equity distributions; incur additional indebtedness; incur or make any capital expenditures; materially amend, or terminate, any of our current charter contracts or management agreements; or charter our vessels.
Our loan agreements and lease financing arrangements also require us to maintain specific financial ratios, including minimum amounts of unrestricted cash, minimum ratios of current assets to current liabilities (excluding but not limited to the current portion of long-term debt, VIE balances), minimum levels of stockholders’ equity and maximum loan amounts to value. If we were to fail to maintain these levels and ratios without obtaining a waiver of covenant compliance or modification to our covenants, we would be in default of our loans and lease financing agreements, which, unless waived by our lenders, could provide our lenders with the right to require us to increase the minimum value held by us under our equity and liquidity covenants, increase our interest payments, pay down our indebtedness to a level where we are in compliance with our loan covenants, sell vessels in our fleet or reclassify our indebtedness as current liabilities and could allow our lenders to accelerate our indebtedness and foreclose their liens on our vessels, which could result in the loss of our vessels. If our indebtedness is accelerated, we may not be able to refinance our debt or obtain new financing, which would impair our ability to continue to conduct our business.
Events beyond our control, including changes in the economic and business conditions in the shipping industry in which we operate, interest rate developments, changes in the funding costs of our banks, changes in vessel earnings and asset valuations, outbreaks of epidemic and pandemic of diseases and war or geopolitical unrest, may affect our ability to comply with these financial covenants. We cannot provide any assurance that we will continue to meet these ratios or satisfy our financial or other covenants or that our lenders will waive any failure to do so.
•NFE has agreed to indemnify us pursuant to the Golar Partners and Hygo Omnibus Agreements. The inability of NFE to satisfy its indemnity obligations to us could have a material adverse effect on our financial condition and results of operations.
Pursuant to the Golar Partners and Hygo Omnibus Agreements, we are indemnified by NFE for certain losses we may incur in connection with providing guarantees and counter indemnities under certain contracts covered by the Golar Partners and Hygo Omnibus Agreements.
NFE’s ability to make payments to us under the Golar Partners Omnibus Agreement and the Hygo Omnibus Agreement may be affected by events beyond either of the control of NFE or us, including prevailing economic, financial, geopolitical and industry conditions. If NFE is unable to meet its indemnification obligations to us under the Golar Partners Omnibus Agreement or the Hygo Omnibus Agreement, our financial condition, results of operations and ability to make cash distributions to shareholders could be materially adversely affected.
•If the Hilli LC is not extended, the earnings and financial condition of Hilli Corp could suffer.
Pursuant to the terms of the LTA, Golar obtained a LC issued by a financial institution that guarantees certain payments Hilli Corp, a wholly owned subsidiary, is required to make under the LTA. The LC was set to expire on December 31, 2019, but it automatically extends for successive one-year periods until the tenth anniversary of the acceptance of the Hilli to perform the agreed services for the project, unless the financial institution elects to not extend the LC. The financial institution may elect to not extend the LC by giving notice at least ninety days prior to December 31 in any subsequent year. If the LC (i) ceases to be in effect or (ii) the financial institution elects to not extend it, unless replacement security for payment is provided within a certain time, then the LTA may be terminated and Hilli Corp may be liable for a termination fee of up to $125 million. Accordingly, if the financial institution elects at some point in the future to not extend the LC, Hilli Corp's financial condition could be materially and adversely affected.
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•We are exposed to volatility in LIBOR and the derivative contracts we have entered into to hedge our exposure to fluctuations in interest rates could result in higher than market interest rates and charges against our income.
LIBOR is the subject of recent national, international and other regulatory guidance and proposals for reform. In March 2021, the UK Financial Conduct Authority, which regulates LIBOR, announced that it will cease the publication of LIBOR after December 31, 2021, except for certain tenors of U.S. dollar LIBOR which will cease publication after June 30, 2023. It is unclear whether an extension will be granted or new methods of calculating LIBOR will be established such that it continues to exist after the scheduled expiration dates, or if alternative rates will be adopted. Global regulators are working with the financial sector to transition away from the use of LIBOR and towards the adoption of alternative reference rates. The impact of such transition away from LIBOR could be significant for us because of our substantial indebtedness.
While the agreements governing our revolving facilities and secured term loan facilities provide for an alternate method of calculating interest rates if a LIBOR rate is unavailable, once LIBOR ceases to exist, there may be adverse impacts on the financial markets generally and interest rates on borrowings under our revolving facilities and secured term loan facilities may be materially adversely affected.
In addition, we may need to renegotiate certain LIBOR-based revolving credit facilities, term loan facilities, interest rate swaps and finance lease facilities, which could adversely impact our cost of debt. There can be no assurance that we will be able to modify existing documentation or renegotiate existing transactions before the discontinuation of U.S. dollar LIBOR tenors by June 30, 2023.
•Servicing our debt agreements substantially limits our funds available for other purposes and our operational flexibility.
Our ability to service our indebtedness will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, regulatory, war or geopolitical unrest and other factors, some of which are beyond our control. If our operating income is not sufficient to service our indebtedness, we will be forced to take actions, such as reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing our debt or seeking additional equity capital. We may not be able to effect any of these remedies on satisfactory terms, or at all. In addition, a lack of liquidity in the debt and equity markets could hinder our ability to refinance our debt or obtain additional financing on favorable terms in the future.
•Our consolidated lessor VIEs, may enter into different financing arrangements, which could affect our financial results.
Following the sale and leaseback transactions we have entered into with certain affiliates of Chinese financial institutions that are determined to be lessor VIEs, where we are deemed to be the primary beneficiary, we are required by U.S. GAAP to consolidate these lessor VIEs into our financial results. Although consolidated into our results, we have no control over the funding arrangements negotiated by these lessor VIEs such as interest rates, maturity and repayment profiles. The funding arrangements negotiated by these lessor VIEs could adversely affect our financial accounting results.
As of April 14, 2022 and subsequent to the completion of the transactions contemplated under the Cool Co Vessel SPA, we have deconsolidated seven of our eight lessor VIEs. For additional detail refer to note 5 “Variable Interest Entities” and note 30 “Subsequent events” of our consolidated financial statements included herein.
Risks related to our operations
•A cyber-attack could materially disrupt our business.
We rely on information technology systems and networks in our operations and the administration of our business. Cyber-attacks have increased in number and sophistication in recent years. Our operations could be targeted by individuals or groups seeking to sabotage or disrupt our information technology systems and networks, or to steal data. A successful cyber-attack could materially disrupt our operations, including the safety of our operations, or lead to unauthorized release of information or alteration of information on our systems. Any such attack or other breaches of our information technology systems could have a material adverse effect on our business and results of operations.
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•A substantial increase in operating costs could materially and adversely affect our financial performance.
Our vessel operating expenses and dry-dock capital expenditures depends on a variety of factors, including crew costs, provisions, deck and engine stores and spares, lubricating oil, insurance, maintenance and repairs and shipyard costs, many of which are beyond our control and affect the entire shipping industry.
While we do not bear the cost of fuel under our time charters, fuel is a significant, if not the largest, expense in our operations when our vessels are operating under voyage charters, are idling during periods of commercial waiting time or when positioning or repositioning before or after a time charter. The price and supply of fuel is unpredictable and fluctuates based on events outside of our control, including, supply and demand for oil and gas, actions by the Organization of Petroleum Exporting Countries and other oil and gas producers, war and unrest in oil and gas producing countries and regions, regional productions patterns and environmental concerns. Fuel costs may fluctuate significantly, and if costs rise, they could materially and adversely affect our results of operations.
•Marine transportation and oil production are inherently risky and our operations face several industry risks and events which could cause damage or loss of a vessel, loss of life or environmental consequences that could harm our reputation and ongoing business operations.
Our vessels and their cargoes are at risk of being damaged or lost because of events such as marine disasters, outbreaks of epidemic and pandemic diseases, acts of piracy, environmental accidents, bad weather, mechanical failures, grounding, fire, explosions and collisions, human error, national emergency and war and terrorism. Incidents such as these have historically affected companies in our industry, and such an event or accident involving any of our vessels could result in any of the following:
•death or injury to persons, loss of property or environmental damage;
•delays in the delivery of cargo;
•the inability to complete scheduled engine overhauls, routine maintenance work, vessel inspections, certifications by class societies and management of equipment malfunctions;
•loss of revenues from or termination of charter contracts;
•governmental fines, penalties or restrictions on conducting business;
•a government requisitioning for title or seizing our vessels (e.g. in a time of war or national emergency);
•higher insurance rates; and
•damage to our reputation and customer relationships generally.
Any of these circumstances or events could increase our costs or lower our revenues. In particular:
•although we carry insurance, all risks may not be adequately insured against, and any claim may not be paid. Any claims covered by insurance would be subject to deductibles, and since it is possible that a large number of claims may be brought, the aggregate amount of these deductibles could be material;
•if piracy attacks, military action or war results in regions in which our vessels are deployed being characterized as “war risk” zones by insurers or the Joint War Committee “war and strikes” listed areas, premiums payable for such coverage could increase significantly and such insurance coverage may be more difficult to obtain;
•certain of our insurance coverage is maintained through mutual protection and indemnity associations and, as a member of such associations, we may be required to make additional payments over and above budgeted premiums if member claims exceed association reserves;
•if our vessels suffer damage, they may need to be repaired. The costs of vessel repairs are unpredictable and can be substantial. We may have to pay repair costs that our insurance policies do not cover. The loss of earnings while these vessels are being repaired, as well as the actual cost of these repairs, would decrease our results of operations; and
•if one of our vessels were involved in an accident with the potential risk of environmental contamination, the resulting media coverage could have a material adverse effect on our business, our results of operations and cash flows, weaken our financial condition and negatively affect our ability to pay distributions.
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•Failure to comply with the U.S. Foreign Corrupt Practices Act, the UK Bribery Act and other anti-bribery legislation in other jurisdictions could result in fines, criminal penalties, contract terminations and an adverse effect on our business.
We may operate in several countries throughout the world, including countries known to have a reputation for corruption. We are committed to doing business in accordance with applicable anti-corruption laws and have adopted a code of business conduct and ethics which is consistent and in full compliance with the U.S. Foreign Corrupt Practices Act of 1977 (“FCPA”), and the Bribery Act 2010 of the UK (“UK Bribery Act”). We are subject, however, to the risk that we, our affiliated entities or our or their respective officers, directors, employees and agents may take actions determined to be in violation of such anti-corruption laws, including the FCPA and the UK Bribery Act. Any such violation could result in substantial fines, sanctions, civil and/or criminal penalties, curtailment of operations in certain jurisdictions, and might adversely affect our business, results of operations or financial condition. In addition, actual or alleged violations could damage our reputation and ability to do business. Furthermore, detecting, investigating, and resolving actual or alleged violations is expensive and can consume significant time and attention of our senior management.
To effectively compete in some foreign jurisdictions, we utilize local agents and/or establish entities with local operators or strategic partners. All these activities may involve interaction by our agents with government officials. Even though some of our agents or partners may not themselves be subject to FCPA, the UK Bribery Act, or other anti-bribery laws to which we may be subjected to, if our agents or partners make improper payments to government officials or other persons in connection with engagements or partnerships with us, we could be investigated and potentially found liable for violation of such anti-bribery laws and could incur civil and criminal penalties and other sanctions, which could have a material adverse effect on our business and results of operations.
•Vessel values may fluctuate substantially and, if these values are lower at a time when we are attempting to dispose of vessels, we may incur a loss.
Vessel values can fluctuate substantially over time due to several different factors, including:
•prevailing economic and market conditions in the natural gas and energy markets;
•a substantial or extended decline in demand for LNG;
•increases in the supply of vessel capacity without a commensurate increase in demand;
•the type, size and age of a vessel;
•competition from more technologically advanced vessels; and
•the cost of new buildings or retrofitting or modifying existing vessels, as a result of technological advances in vessel design or equipment, changes in applicable environmental or other regulations or standards, customer requirements or otherwise.
As our vessels age, the expenses associated with maintaining and operating them are expected to increase, which could have an adverse effect on our business and operations.
The carrying values of our vessels may not represent their fair market value at any point in time because the market prices of secondhand vessels tend to fluctuate with changes in charter rates and the cost of new build vessels. Our vessels are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Any impairment charges incurred as a result of declines in charter rates could negatively affect our business, financial condition, operating results or the trading price of our common shares.
Please refer to “Item 5. Operating and Financial Review and Prospects B. Liquidity and Capital Resources-Critical Accounting Policies and Estimates-Vessel Market Values” for further information.
•We will have to make additional contributions to our pension scheme because it is underfunded.
We provide pension plans for certain of our current and former marine employees. Members do not contribute to the pension scheme plans and these pension schemes are closed to any new members. As of December 31, 2021, one of the plans is underfunded by $34.8 million. We may need to increase our contributions in order to meet the scheme's liabilities as they fall due, or, to reduce the deficit. Such contributions could have a material and adverse effect on our cash flows and financial condition.
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•We are exposed to U.S. dollar and foreign currency fluctuations and devaluations that could harm our reported revenue and results of operations.
Our principal currency for our operations and financing is the U.S. dollar. We generate most of our revenues in the U.S. dollar. Apart from the U.S. dollar, we incur operating and administrative expenses in multiple currencies. Due to a portion of our expenses being incurred in currencies other than the U.S. dollar, our expenses may, from time to time, increase relative to our revenues as a result of fluctuations in exchange rates, particularly between the U.S. dollar and the Euro, the British Pound, and the Norwegian Kroner, which could affect our earnings. We use financial derivatives to hedge some of our currency exposures. Our use of financial derivatives involves certain risks, including the risk that losses on a hedged position could exceed the nominal amount invested in the instrument and the risk that the counterparty to the derivative transaction may be unable or unwilling to satisfy its contractual obligations, which could have an adverse effect on our results.
•We may be unable to attract and retain key personnel, which may negatively impact the effectiveness of our management and our results of operations.
Our success depends, to a significant extent, upon the abilities and the efforts of our senior executives and certain key employees. While we believe that we have an experienced team, the loss or unavailability of one or more of our senior executives and/or the key employees for any extended period of time could have an adverse effect on our business and results of operations.
•We may be subject to litigation that, if not resolved in our favor and not sufficiently insured against, could have a material adverse effect on us.
We may be, from time to time, involved in various litigation matters. These matters may include, among other things, contract disputes, personal injury claims, environmental claims or proceedings, asbestos and other toxic tort claims, employment matters, governmental claims for taxes or duties and other litigation that arises in the ordinary course of our business.
Although we always intend to defend such matters vigorously, we cannot predict with certainty the outcome or effect of any claim or other litigation matter, and the ultimate outcome of any litigation or the potential costs to resolve them may have a material adverse effect on us. Insurance may not be applicable or sufficient in all cases and/or insurers may not remain solvent, which may have a material adverse effect on our financial condition. Please read “Item 8 Financial Information-Legal Proceedings and Claims”
Risks related to our industry
•Our results of operations and financial condition depend on demand for LNG, LNG carriers, FSRUs and FLNGs.
Our results of operations and financial condition depend on continued world and regional demand for LNG, LNG carriers, FSRUs and FLNGs, which could be negatively affected by several factors, including but not limited to:
•price and availability of natural gas, crude oil and petroleum products;
•increases in the cost of natural gas derived from LNG relative to the cost of natural gas;
•decreases in the cost of, or increases in the demand for, conventional land-based regasification and liquefaction systems, which could occur if providers or users of regasification or liquefaction services seek greater economies of scale than FSRUs or FLNGs can provide, or if the economic, regulatory or political challenges associated with land-based activities improve;
•further development of, or decreases in the cost of, alternative technologies for vessel-based LNG regasification or liquefaction;
•increases in the production levels of low-cost natural gas in domestic natural gas consuming markets, which could further depress prices for natural gas in those markets and make LNG uneconomical;
•increases in the production of natural gas in areas linked by pipelines to consuming areas, the extension of existing, or the development of new, pipeline systems in markets we may serve, or the conversion of existing non-natural gas pipelines to natural gas pipelines in those markets;
•negative global or regional economic or political conditions, particularly in LNG-consuming regions, could reduce energy consumption or its growth;
•geopolitical unrest or war;
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•decreases in the consumption of natural gas due to increases in its price relative to other energy sources or other factors making consumption of natural gas less attractive;
•any significant explosion, spill or other incident involving an LNG facility or carrier, conventional land-based regasification or liquefaction system, or FSRU or FLNG;
•new taxes or regulations affecting LNG production or liquefaction that make LNG production less attractive;
•a significant increase in the number of LNG carriers, FSRUs or FLNGs available, whether by a reduction in the scrapping of existing vessels or the increase in construction of vessels;
•increases in interest rates or other events that may affect the availability of sufficient financing for LNG projects on commercially reasonable terms;
•the inability of project owners or operators to obtain governmental approvals to construct or operate LNG facilities;
•local community resistance to proposed or existing LNG facilities based on safety, environmental or security concerns;
•labor or political unrest affecting existing or proposed areas of LNG production, liquefaction and regasification; and
•availability of new, alternative energy sources, including compressed natural gas.
Reduced demand for LNG or LNG liquefaction, storage, shipping or regasification, or any reduction or limitation in LNG production capacity, could have a material adverse effect on prevailing charter rates or the market value of our vessels, which could have a material adverse effect on our results of operations and financial condition.
•Maritime claimants could arrest our vessels, which could interrupt our cash flow.
If we are in default on certain kinds of obligations, such as those to our lenders, crew members, suppliers of goods and services to our vessels or shippers of cargo, these parties may be entitled to a maritime lien against one or more of our vessels. In many jurisdictions, a maritime lien holder may enforce its lien by arresting a vessel through foreclosure proceedings. Under some of our present charters, if the vessel is arrested or detained (for as few as 14 days in the case of one of our charters) because of a claim against us, we may be in default of our charter and the charterer may terminate the charter. This would negatively impact our revenues and reduce our cash available for distribution to shareholders.
•Political, governmental and economic instability and sanctions or embargoes imposed by the U.S. or other governmental authorities could adversely affect our business.
Although we conduct most of our operations outside of the U.S., the operations of certain of our customers may be adversely affected by changing economic, political and government conditions in the countries and regions where our vessels are employed or registered. Moreover, we operate in, and/or are pursuing projects in areas of the world that is likely to be adversely impacted by the effects of political conflicts, including the current political instability in Ukraine, Cameroon, the Middle East and the South China Sea region, terrorist or other attacks, and war (or threatened war) or international hostilities. These uncertainties could also adversely affect our ability to obtain additional financing on terms acceptable to us or at all. Any of these occurrences could have a material adverse impact on our operating results.
Political instability has also resulted in attacks on vessels, mining of waterways and other efforts to disrupt international shipping, particularly in the Arabian Gulf region and most recently in the Black Sea in connection with the conflict between Russia and Ukraine. This conflict has resulted in several countries and international organizations, such as the U.S., the UK and the EU, imposing trade and investment sanctions against Russia which are expected to adversely affect the global economy. While our vessels and their respective charterers are not directly impacted by these measures, these factors could also increase our costs of conducting our business, particularly crew, insurance and security costs, and prevent or restrict us from obtaining insurance coverage, all of which have may have a material adverse effect on our business, financial condition, results of operations and cash flows.
In addition, tariffs, trade embargoes and other economic sanctions by the U.S. or other countries, against countries in which we operate, or to which we trade, or to which we or any of our customers, joint venture partners or business partners become subjected to, could harm our business. We could be subjected to monetary fines, penalties, or other sanctions, and our reputation and the market for our common shares could be adversely affected if we were found to be in a violation of sanctions or embargo laws.
Further, governments may turn to trade barriers to protect their domestic industries against foreign imports, thereby depressing shipping demand. This could have a material adverse effect on our business, results of operations, financial condition and our ability to pay any cash distributions to our shareholders.
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•Our operations are subject to extensive and changing laws, regulations and reporting requirements, which may have an adverse effect on our business.
Our operations are affected by extensive and changing laws, regulations and reporting requirements that could create greater reporting obligations and compliance requirements. Whilst the regulatory environment continues to evolve, we have invested in, and intend to continue to invest in, reasonably necessary resources to comply with evolving standards and maintain high standards of corporate governance and public disclosure. Compliance with and limitations imposed by these laws, regulations, treaties, conventions, and other requirements, and any future additions or changes to such environmental, health, safety and maritime conduct laws or requirements applicable to international and national maritime trade, may increase our costs and/or limit our operations and have an adverse effect on our business. Failure to comply can result in administrative and civil penalties, criminal sanctions or the suspension or termination of our operations, including, in certain instances, seizure or detention of our vessels.
•Climate change and greenhouse gas restrictions may adversely impact our operations and markets.
An increasing concern for, and focus on climate change has promoted extensive existing and proposed international, national and local regulations intended to reduce greenhouse gas emissions (including from various jurisdictions and the International Maritime Organization (the “IMO”). These regulatory measures may include the adoption of cap-and-trade regimes, carbon taxes, increased efficiency standards and incentives or mandates for renewable energy. Compliance with changes in laws and regulations relating to climate change could increase our costs of operating and maintaining our vessels and could require us to make significant financial expenditures that we cannot predict with certainty at this time.
Adverse effects upon the oil and gas industry relating to climate change, including growing public concern about the environmental impact of climate change, may also influence demand for our services. Any long-term material adverse effect on the oil and gas industry could have a significant financial and operational adverse impact on our business that we cannot predict with certainty at this time.
•Increasing scrutiny and changing expectations from investors, lenders and other market participants with respect to our Environmental, Social and Governance (“ESG”) policies may impose additional costs on us or expose us to additional risks.
We may face increasing pressures from investors, lenders and other market participants, who are increasingly focused on climate change, to prioritize sustainable energy practices, reduce our carbon footprint and promote sustainability. As a result, we may be required to implement more stringent ESG procedures or standards so that our existing and future investors and lenders remain invested in us and make further investments in us, especially given the highly focused and specific trade of liquefaction, transportation and regasification of LNG in which we are engaged. If we do not meet these standards, our business and/or our ability to access capital could be harmed.
Additionally, certain investors and lenders may exclude companies engaged in the liquefaction, transportation and regasification of LNG, such as us, from their investing portfolios altogether due to ESG factors. These limitations in both the debt and equity capital markets may affect our ability to grow as our plans for growth may include accessing the equity and debt capital markets. If those markets are unavailable, or if we are unable to access alternative means of financing on acceptable terms, or at all, we may be unable to implement our business strategy, which would have a material adverse effect on our financial condition and results of operations and impair our ability to service our indebtedness. Further, it is likely that we will incur additional costs and require additional resources to monitor, report and comply with wide ranging ESG requirements. The occurrence of any of the foregoing could have a material adverse effect on our business and financial condition.
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Risks related to our common shares
•The declaration and payment of dividends is at the discretion of our board of directors.
The declaration and payment of dividends to holders of our common shares will be at the discretion of our board of directors in accordance with applicable law. In determining whether to declare and pay a dividend, our board of directors will take into account various factors, including actual results of operations, liquidity and financial condition, net cash provided by operating activities, restrictions imposed by applicable law, our taxable income, our operating expenses and other factors our board of directors deem relevant. There can be no assurance that we will continue to pay dividends in amounts or on a basis consistent with prior distributions to our investors, if at all. Because we are a holding company and have no direct operations, we will only be able to pay dividends from our available cash on hand and any funds we receive from our subsidiaries and our ability to receive distributions from our subsidiaries may be limited by the financing agreements to which they are subject.
•If we fail to meet the expectations of analysts or investors, our share price could decline substantially.
In some quarters, our results may be below analysts’ or investors’ expectations. If this occurs, the price of our common stock could decline. Important factors that could cause our revenue and operating results to fluctuate from quarter to quarter or year on year, include, but are not limited to:
•prevailing economic and market conditions in the natural gas and energy markets;
•negative global or regional economic or political conditions, particularly in LNG-consuming regions, which could reduce energy consumption or its growth;
•declines in demand for LNG or the services of LNG carriers, FSRUs or FLNGs;
•increases in the supply of LNG carrier capacity operating in the spot market or the supply of FSRUs or FLNGs;
•marine disasters, war, piracy or terrorism, environmental accidents, or inclement weather conditions;
•mechanical failures or accidents involving any of our vessels; and
•dry-dock scheduling and capital expenditures.
Most of these factors are not within our control, and the occurrence of one or more of them may cause our operating results to vary widely.
•Our common share price may be highly volatile and future sales of our common shares could cause the market price of our common shares to decline and could lead to a loss of all or part of a shareholder's investment.
The market price of our common shares has fluctuated widely since they began trading on the NASDAQ Global Select Market. We cannot assure you that an active and liquid public market for our common shares will continue. Over the last few years, the stock market has experienced price and volume fluctuations. From January 1, 2021, the closing market price of our common shares on Nasdaq ranged from a low of $10.30 in August 2021 to a high of $26.36 per share in April 2022.
The market price of our common shares may experience extreme volatility in response to many factors, including factors that may be unrelated to our operating performance or prospects such as actual or anticipated fluctuations in our quarterly or annual results and those of other public companies in our industry, the suspension of our dividend payments, mergers and strategic alliances in the shipping industry, market conditions in the LNG shipping industry, developments in our FLNG investments, shortfalls in our operating results from levels forecast by securities analysts, announcements concerning us or our competitors, business interruptions, the general state of the securities market, and other factors, many of which are beyond our control.
Furthermore, following periods of volatility in the market, securities class-action litigation has often been instituted against companies. Such litigation, if instituted against us, could result in substantial costs and diversion of management’s attention and resources, which could materially and adversely affect our business, financial condition, results of operations and growth prospects. Additionally, sales of a substantial number of our common shares in the public market, or the perception that these sales could occur, may depress the market price for our common shares. These sales could also impair our ability to raise additional capital through the sale of our equity securities in the future. Therefore, there can be no guarantee that our stock price will remain at current prices, and we cannot assure our shareholders that they will be able to sell any of our common shares that they may have purchased at a price greater than or equal to the original purchase price.
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•We may issue additional common shares or other equity securities without our shareholders’ approval, which would dilute their ownership interests and may depress the market price of our common shares.
We may issue additional common shares or other equity securities in the future in connection with, among other things, vessel conversions, future vessel acquisitions, repayment of outstanding indebtedness or our equity incentive plan, in each case without shareholder approval in several circumstances.
Our issuance of additional common shares or other equity securities would have the following effects:
•our existing shareholders’ proportionate ownership interest in us will decrease;
•the amount of cash available for dividends payable on our common shares may decrease;
•the relative voting strength of each previously outstanding common share may be diminished; and
•the market price of our common shares may decline.
•Because we are a Bermuda corporation, our shareholders may have less recourse against us or our directors than shareholders of a U.S. company have against the directors of that U.S. Company.
Because we are a Bermuda company, the rights of holders of our common shares will be governed by Bermuda law and our memorandum of association and bye-laws. The rights of shareholders under Bermuda law may differ from the rights of shareholders in other jurisdictions, including with respect to, among other things, rights related to interested directors, amalgamations, mergers and acquisitions, takeovers, the exculpation and indemnification of directors and shareholder lawsuits.
Among these differences is a Bermuda law provision that permits a company to exempt a director from liability for any negligence, default, or breach of a fiduciary duty except for liability resulting directly from that director’s fraud or dishonesty. Our bye-laws provide that no director or officer shall be liable to us or our shareholders unless the director’s or officer’s liability results from that person’s fraud or dishonesty. Our bye-laws also require us to indemnify a director or officer against any losses incurred by that director or officer resulting from their negligence or breach of duty, except where such losses are the result of fraud or dishonesty. Accordingly, we carry directors’ and officers’ insurance to protect against such a risk.
In addition, under Bermuda law, the directors of a Bermuda company owe their duties to that company and not to the shareholders. Bermuda law does not, generally, permit shareholders of a Bermuda company to bring an action for a wrongdoing against the company or its directors, but rather the company itself is generally the proper plaintiff in an action against the directors for a breach of their fiduciary duties. Moreover, class actions and derivative actions are generally not available to shareholders under Bermuda law. These provisions of Bermuda law and our bye-laws, as well as other provisions not discussed here, may differ from the law of jurisdictions with which shareholders may be more familiar and may substantially limit or prohibit a shareholder's ability to bring suit against our directors or in the name of the company. The Bermuda courts, however, would ordinarily be expected to permit a shareholder to commence an action in the name of a company to remedy a wrong to the company where the act complained of is alleged to be beyond the corporate power of the company or illegal, or would result in the violation of the company’s memorandum of association or bye-laws. Furthermore, consideration would be given by a Bermuda court to acts that are alleged to constitute a fraud against minority shareholders or, for instance, where an act requires the approval of a greater percentage of the company’s shareholders than that which actually approved it.
It's also worth noting that under Bermuda law, our directors and officers are required to disclose to our board any material interests they have in any contract entered into by our company or any of its subsidiaries with third parties. Our directors and officers are also required to disclose their material interests in any corporation or other entity which is party to a material contract with our company or any of its subsidiaries. A director who has disclosed his or her interests in accordance with Bermuda law may participate in any meeting of our board, and may vote on the approval of a material contract, notwithstanding that he or she has a material interest.
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•Because our offices and most of our assets are outside the U.S., our shareholders may not be able to bring a suit against us, or enforce a judgment obtained against us in the United States.
We, and most of our subsidiaries, are incorporated in jurisdictions outside the U.S. and substantially all of our assets and those of our subsidiaries are located outside the U.S. In addition, most of our directors and officers are non-residents of the U.S., and all or a substantial portion of the assets of these non-residents are located outside the U.S. As a result, it may be difficult or impossible for U.S. investors to serve process within the U.S. upon us, our subsidiaries, or our directors and officers, or to enforce a judgment against us for civil liabilities in U.S. courts. In addition, you should not assume that courts in the countries in which we or our subsidiaries are incorporated or where our or our subsidiaries’ assets are located would enforce judgments of U.S. courts obtained in actions against us or our subsidiaries based upon the civil liability provisions of applicable U.S. federal and state securities laws, or would enforce, in original actions, liabilities against us or our subsidiaries based on those laws.
Risks related to tax
•As a Bermuda exempted company incorporated under Bermuda law with subsidiaries in the Marshall Islands and other offshore jurisdiction, our operations may be subject to economic substance requirements.
On December 5, 2017, following an assessment of the tax policies of various countries by the Code of Conduct Group for Business Taxation of the European Union (the “COCG”), the Council of the European Union (the “Council”) approved and published Council conclusions containing a list of “non-cooperative jurisdictions” for tax purposes. On March 12, 2019, the Council adopted a revised list of non-cooperative jurisdictions (the “2019 Conclusions”). In the 2019 Conclusions, Bermuda and the Republic of the Marshall Islands, among others, were placed by the E.U. on its list of non-cooperative jurisdictions for tax purposes for failing to implement certain commitments previously made to the E.U. by the agreed deadline. However, it was announced by the Council on May 17, 2019 and on October 10, 2019 that Bermuda and the Marshall Islands, respectively, had been removed from the list of non-cooperative tax jurisdictions. The E.U. member states have agreed upon a set of measures, which they can choose to apply against the listed countries, including increased monitoring and audits, withholding taxes, special documentation requirements and anti-abuse provisions. The European Commission has stated it will continue to support member states’ efforts to develop a more coordinated approach to sanctions for the listed countries, E.U. legislation prohibits E.U. funds from being channelled or transited through entities in non-cooperative jurisdictions.
We are a Bermuda exempted company incorporated under Bermuda law with principal executive offices in Bermuda. Certain of our subsidiaries are Marshall Islands entities. Both Bermuda and the Marshall Islands have enacted, economic substance laws and regulations with which we may be obligated to comply. For example, on December 17, 2018, the House of Assembly of Bermuda passed the Economic Substance Act 2018 of Bermuda (the “Economic Substance Act”), which became operative on December 31, 2018, along with the Economic Substance Regulations 2018 of Bermuda. The Economic Substance Act requires each registered entity to maintain a substantial economic presence in Bermuda and provides that a registered entity that carries on a relevant activity must comply with economic substance requirements set out in the legislation. Regulations were also adopted in the Marshall Islands, through Economic Substance Regulations 2018 which came into force in January 2019, and with Guidance Notes being published in October 2019, requiring certain entities that carry out activities to comply with an economic substance test and satisfy certain reporting obligations, beginning with the financial period which ended in 2020.
If we fail to comply with our obligations under this legislation, as it may be amended from time to time, or any similar or supplemental law applicable to us in these or any other jurisdictions, we could be subject to financial penalties and spontaneous disclosure of information to foreign tax officials, or could be removed from the register of companies, in related jurisdictions. Any of the foregoing could be disruptive to our business and could have a material adverse effect on our business, financial conditions and operating results.
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•A change in tax laws in any country in which we operate could adversely affect us.
Tax laws, treaties and regulations are highly complex and subject to interpretation. Consequently, we and our subsidiaries are subject to changing laws, treaties and regulations in and between the countries in which we operate. Our tax expense is based on our interpretation of the tax laws in effect at the time the expense was incurred. A change in tax laws, treaties or regulations, or in the interpretation thereof, could result in a materially higher tax expense or a higher effective tax rate on our earnings. Such changes may include measures enacted in response to the ongoing initiatives in relation to fiscal legislation at an international level such as the Action Plan on Base Erosion and Profit Shifting of the Organization for Economic Co-Operation and Development.
•We could be treated as or become a PFIC, which could have adverse United States federal income tax consequences to U.S. shareholders.
A foreign corporation will be treated as a “passive foreign investment company,” or PFIC, for U.S. federal income tax purposes if either (1) at least 75% of its gross income during the taxable year consists of certain types of “passive income” or (2) at least 50% of the average value of the corporation's assets during such taxable year produce or are held for the production of those types of “passive income.” For purposes of these tests, “passive income” includes dividends, interest, and gains from the sale or exchange of investment property and rents and royalties other than rents and royalties which are received from unrelated parties in connection with the active conduct of a trade or business. For purposes of these tests, income derived from the performance of services does not constitute “passive income.” U.S. shareholders of a PFIC are subject to a disadvantageous U.S. federal income tax regime with respect to the income derived by the PFIC, the distributions they receive from the PFIC and the gain, if any, they derive from the sale or other disposition of their shares in the PFIC.
We intend to treat the gross income we derive or are deemed to derive from our time chartering activities as services income, rather than rental income. Accordingly, we believe that our income from our time chartering activities does not constitute “passive income,” and the assets that we own and operate in connection with the production of that income do not constitute passive assets.
We believe there is substantial legal authority supporting our position consisting of case law and United States Internal Revenue Service, or IRS, pronouncements concerning the characterization of income derived from time charters and voyage charters as services income for other tax purposes. However, we note that there is also authority which characterizes time charter income as rental income rather than services income for other tax purposes. Accordingly, no assurance can be given that the IRS or a court of law will accept our position.
Based on the foregoing, we believe that we were not a PFIC with respect to any prior taxable year. However, there can be no assurance that we will not become a PFIC for any future taxable year as a result of changes in our operations or assets.
If we are or have been a PFIC for any taxable year, our U.S. shareholders will face adverse U.S. tax consequences and certain information reporting requirements. Under the PFIC rules, unless those shareholders make a certain election available (which election could itself have adverse consequences for such shareholders), such shareholders would be liable to pay U.S. federal income tax at the then prevailing income tax rates on ordinary income plus interest upon excess distributions and upon any gain from the disposition of our common shares, as if the excess distribution or gain had been recognized ratably over the shareholder's holding period of our common shares. Please see the section of this annual report entitled “Taxation” under “Item 10. Additional Information E. Taxation” for a more comprehensive discussion of the U.S. federal income tax consequences if we were to be treated as a PFIC.
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•We may have to pay tax on U.S. source income, which would reduce our earnings.
Under the U.S. Internal Revenue Code of 1986 as amended, or the Code, 50% of the gross shipping income of a vessel owning or chartering corporation, such as ourselves and our subsidiaries, that is attributable to transportation that begins or ends, but that does not both begin and end, in the U.S., may be subject to a 4% U.S. federal income tax without allowance for deduction, unless that corporation qualifies for exemption from tax under Section 883 of the Code and the applicable Treasury Regulations recently promulgated thereunder.
We expect that we and each of our subsidiaries will qualify for this statutory tax exemption and we will take this position for U.S. federal income tax return reporting purposes. However, there are factual circumstances beyond our control that could cause us to lose the benefit of this tax exemption and thereby become subject to U.S. federal income tax on our U.S. source income. Therefore, we can give no assurances that this tax exemption will apply to us or to any of our subsidiaries.
If we or our subsidiaries are not entitled to exemption under Section 883 of the Code for any taxable year, we or our subsidiaries could be subject for those years to an effective 4% U.S. federal income tax on the gross shipping income we or our subsidiaries derive during the year that are attributable to the transport of cargoes to or from the United States. The imposition of this tax would have a negative effect on our business and would result in decreased earnings available for distribution to our shareholders. Please see “Item 10. Additional Information-E. Taxation” for further information.
•We may become subject to taxation in Bermuda which would negatively affect our results.
At the present time, there is no Bermuda income or profits tax, withholding tax, capital gains tax, capital transfer tax, estate duty or inheritance tax payable by us or by our shareholders in respect of our shares. We have obtained an assurance from the Minister of Finance of Bermuda under the Exempted Undertakings Tax Protection Act 1966 that, in the event that any legislation is enacted in Bermuda imposing any tax computed on profits or income, or computed on any capital asset, gain or appreciation or any tax in the nature of estate duty or inheritance tax, such tax shall not, until March 31, 2035, be applicable to us or to any of our operations or to our shares, debentures or other obligations except insofar as such tax applies to persons ordinarily resident in Bermuda or is payable by us in respect of real property owned or leased by us in Bermuda. We cannot assure you that a future Minister would honor that assurance, which is not legally binding, or that after such date we would not be subject to any such tax. If we were to become subject to taxation in Bermuda, our results of operations could be adversely affected.
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ITEM 4. INFORMATION ON THE COMPANY
A. History and Development of the Company
Overview
Golar LNG Limited designs, builds, owns and operates marine infrastructure for the liquefaction and regasification of LNG. Following the disposal of our investments in former affiliates Golar Partners and Hygo in April 2021 and the recent business separation of our eight modern TFDE LNG vessels into Cool Co in April 2022, we have narrowed our focus on pursuing and increasing our portfolio of FLNG projects.
We believe that natural gas has a critical role to play in providing cleaner energy for many years to come. Our mission is to be recognized as a learning organization with an outstanding reputation for safe, reliable and cost-effective operations; to employ and develop talented people who can see the impact of what they do; to develop a pipeline of new FLNG infrastructure opportunities and convert the best opportunities into world class projects; and to be a great business partner, where combining skills and resources make a big difference.
Our strategy is to offer resource holders a low-cost quick delivering solution to monetize stranded gas reserves. Our unique industry leading FLNG technology allows stranded and associated gas resource holders, developers and customers to enter the LNG business and occupy a legitimate space alongside the largest resource holders, major oil companies and world-scale LNG buyers. For established LNG industry participants, the prospect of our low-cost, low-risk, fast-track, small footprint FLNG solution provides a compelling alternative to traditional land-based projects. As one of the industry’s most innovative developers of floating terminals, Golar has produced more LNG from a floating facility than any other operator.
As of April 14, 2022, our fleet of vessels is comprised of one LNG carrier, one FSRU and two FLNGs (including the operational FLNG Hilli and the Gimi which is currently under conversion) and one FLNG conversion candidate vessel, the Gandria.
We are listed on Nasdaq under the ticker “GLNG”. We were incorporated under the name Golar LNG Limited as an exempted company under the Bermuda Companies Act of 1981 in the Islands of Bermuda on May 10, 2001 and maintain our principal executive headquarters at 2nd Floor, S.E. Pearman Building, 9 Par-la-Ville Road, Hamilton HM 11, Bermuda. Our telephone number at that address is +1 441 295 4705. Our principal administrative offices are located at The Zig Zag, 70 Victoria Street, London, SW1E 6SQ, United Kingdom and our telephone number at that address is +44 207 063 7900. The Commission maintains an internet site that contains reports, proxy and information statements, and other information that we file electronically with the Commission and this can be obtained from the Commission’s website at (http://www.sec.gov) or from the “SEC filings” tab in the “Investor Relations” section of our website (www.golarlng.com). Information contained on our website does not constitute part of this annual report.
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As of April 14, 2022, our existing investments and projects are as follows:
Our investments
a.New Fortress Energy (“NFE”)
In April 2021, we sold to NFE our outstanding interests in the common units and general partner of our former affiliates, Golar Partners for $3.55 per unit (the “GMLP Merger”) and all of our outstanding shares in Hygo (the “Hygo Merger”). We received a total consideration of $80.8 million in cash for Golar's equity stake in GMLP. Concurrently, with the completion of the GMLP Merger, the incentive distribution rights (“IDRs”) of Golar Partners owned by us were cancelled and ceased to exist, and no consideration was paid to us. On the Hygo Merger, the purchase consideration included 18,627,451 shares of NFE common stock (representing 8.9% ownership at the time of closing) and $50 million in cash. In April 2022, we sold 6.2 million shares of NFE common stock raising net proceeds of $253.0 million, which is planned to be deployed for FLNG growth and general corporate purposes.
Furthermore, on 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.
b.Avenir
Avenir is a joint investment with Stolt-Nielsen, Höegh and us for the pursuit of opportunities in small-scale LNG, including the delivery of LNG to areas of stranded gas demand and the development of LNG bunkering services and supply to the transportation sector. During the private placement in 2018, we subscribed for 24.8 million shares, representing an investment of $24.8 million. In 2020, we injected a further $18.0 million and were issued additional shares at a par value of $1.00 per share, bringing our total capital contributions to $42.8 million, representing 23.5% ownership.
Avenir currently has four small-scale LNG newbuilds, one small-scale LNG carrier under construction and an LNG terminal and distribution facility in the Italian port of Oristano, Sardinia.
c.Cool Co
The objective of the formation of the Cool Co is to serve the transportation requirements of the LNG shipping market by providing customers with modern and flexible solutions to meet their shipping requirements. On January 26, 2022, Golar and Cool Co entered into a share purchase agreement (“the Vessel SPA”) under which Cool Co is acquiring eight modern TFDE LNG vessels, namely the Golar Seal, Golar Crystal, Golar Bear, Golar Frost, Golar Glacier, Golar Snow, Golar Kelvin, Golar Ice as well as the Cool Pool Limited, the fleet’s commercial management company (“the Disposal Group”), from Golar. The purchase price for each vessel was agreed at $145.0 million, subject to working capital and debt adjustments.
Following completion of the Vessel SPA, we now hold 31.25% share in Cool Co, while EPS Ventures Ltd is the largest shareholder at 37.50% and the remaining 31.25% held by a group of institutional and other investors.
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Our projects
d. Gimi GTA Project
In February 2019, Golar entered into the LOA with BP for the charter of a FLNG unit, Gimi, to service the BP Greater Tortue Ahmeyim project for a 20-year period, and the Gimi was delivered to a shipyard in Singapore to commence her conversion. The Gimi will liquefy natural gas as part of the first phase of the Gimi GTA Project and will be located at an innovative nearshore hub on the Mauritania and Senegal maritime border. The Gimi is designed to produce an average of approximately 2.5 million tonnes of LNG per annum, with the total gas resources in the field estimated to be around 15 trillion cubic feet.
In April 2020, we announced the receipt of a written notification of a FM claim by BP under the LOA. The FM notice claimed that due to the global outbreak of COVID-19, BP was unable to be ready to receive the converted FLNG Gimi on the 2022 target connection date.
In October 2020, we agreed a revised project schedule with BP for the Gimi GTA Project which resulted in the original 2022 target connection date for the Gimi, to be extended by 11 months. Written notice was received from BP confirming that no FM event (as defined in the LOA) is ongoing. We have concluded discussions with both engineering, procurement and construction contractors and lending banks regarding the adjustment of the related construction and financing schedules, respectively, for the Gimi GTA Project to reflect these changes in the respective agreements. The Gimi conversion cost including financing cost is approximately $1.6 billion of which $700 million is funded by the Gimi debt facility.
As of April 14, 2022, the Gimi conversion is 82% technically complete.
e. LNG Croatia
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 December 2020, we completed the conversion of LNG Croatia and sold the vessel for $193.3 million.
From January 1, 2021 our 10-year Operation and Maintenance Agreement (the “O&M Agreement”) in relation to the FSRU LNG Croatia with LNG Hrvatska commenced.
f. Floating Ammonia Production, Carbon Capture, Green LNG and other emerging technologies
Golar’s internal “Green Team” continues to engage with and evaluate new technologies and partnerships to improve the efficiency of our LNG operations and develop solutions in the field of floating ammonia production, carbon capture, green LNG and hydrogen. For example, in November 2020 we entered into a collaboration agreement with B&V to research and, if appropriate, develop these technologies and released a thought leadership paper on the potential for floating ammonia production.
B. Business Overview
In January 2021, following the board of directors' approvals of the GMLP Merger and Hygo Merger with NFE, we determined that our share of the net earnings/(losses) in our former affiliates, Golar Partners and Hygo and the respective carrying values of our equity accounted investments met the definitions of held for sale and discontinued operations and have consequently presented them as net income/(loss) from discontinued operations and assets held for sale, respectively. Concurrently, the disposal of our interest in Hygo signaled our exit from “Power” operations and we therefore ceased to consider the “Power” operations as a reportable segment.
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Management has concluded that we provide three distinct reportable segments as follows:
•Shipping – We operate and subsequently charter out LNG carriers on fixed terms to customers. We own one LNG carrier and one FSRU, the Golar Tundra which is currently trading as an LNG carrier in the Cool Pool.
•FLNG – We convert LNG carriers into FLNG vessels and subsequently charter them out to customers. We currently have one operational FLNG, the Hilli, one undergoing conversion, the Gimi, and one LNG carrier earmarked for FLNG conversion, the Gandria. We also have ready to implement designs for newbuild FLNGs of varying sizes.
•Corporate and other - Related to our business activities of vessel management and administrative services. This segment also includes our corporate overhead costs.
Corporate and other segment
Golar Management, our wholly-owned subsidiary which has its offices in London, Oslo, Kuala Lumpur and Split, provides commercial, operational and technical support, crew management services and supervision and accounting and treasury services. Golar Management is compensated via management fees for the costs and expenses it incurs in connection with the provision of these services.
As of April 14, 2022, an overview of our assets and investments are as follows:
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Vessel Name | Year of Delivery/Conversion | Capacity Cubic Meters | Flag | Type | Ownership | Charterer/ Pool Arrangement | Current Charter Expiration
Golar Arctic | 2003 | 140,000 | Marshall Islands | LNGC Membrane | 100% | Spot market | Not applicable
Golar Tundra (1) | 2015 | 170,000 | Marshall Islands | FSRU Membrane | 100% | Pool arrangement | 2022
Hilli Episeyo (2) | 2017 | 2.4 mtpa | Marshall Islands | FLNG Moss | -44.6% of the common units -89.1% of each of the Series A and Series B | Perenco/SNH | 2026
Gimi | Conversion in progress | 2.45 mtpa | Marshall Islands | FLNG Moss | 70% | BP | 2043
Gandria (3) | Earmarked for conversion | 126,000 cubic meters | Marshall Islands | Moss | 100% | Not applicable | Not applicable

(1)Vessels in the Cool Pool allow certain substitution rights which means that any vessel within the Cool Pool is interchangeable with another vessel of the same/similar technical specification and may not be considered to be dedicated to a particular charterer. Furthermore, pool earnings are aggregated and then allocated to the pool participants in accordance with the number of days each of their vessels are entered into the pool during the period.
(2)The Hilli is scheduled to provide liquefaction services until the earlier of (i) eight years from May 2018, the date the Customer accepted the Hilli, or (ii) the time of receipt and processing by the Hilli of 500 billion cubic feet of feed gas. The tolling fee is based on a fixed element of hire and also an element related to the price of Brent crude oil where we receive incremental tolling fees when the price rises above $60 per barrel. In 2020, we signed an amendment to the LTA that the Customer will compensate Hilli Corp annually for overproduction of annual base liquefaction tonnage. In 2021, we signed amendments to the LTA to extend the original term of the LTA until July 2026, increase the utilization in 2022 by 0.2 million tons of TTF linked LNG production and granted the Customer a one-time option exercisable by July 2022 to increase capacity utilization of Hilli by up to 0.4 million tons of TTF linked LNG production per year from January 2023 through the end of the current contract term in July 2026.
As of December 31, 2021, the LC provided by a financial institution to the Customer had been reduced to $100 million, following the achievement of 3.6 million tonnes of LNG being produced, and we have cash collateral of $60.7 million to support the Hilli performance guarantee, in the event of termination by the Customer due to underperformance or non-performance.
As of April 14, 2022, the Hilli had offloaded a total of 72 LNG cargoes, produced around 5 million tonnes of LNG, and maintained 100% commercial uptime since the start of her operations in May 2018.
(3)The Gandria is currently in lay-up and earmarked for conversion into a FLNG vessel. The conversion agreement is subject to certain payments and lodging of a full Notice to Proceed.
Competition
We operate in competitive markets that are based primarily on supply and demand.
The FLNG industry is in an early stage of development, and we do not currently face significant competition from other providers of FLNG services. There are currently only six FLNGs on the water and one further FLNG currently under construction. We anticipate that other companies, including marine transportation companies with strong reputations and extensive resources and experience, will enter the FLNG industry at some point in the future, resulting in greater competition.
Competition for carrier and FSRU charters is based primarily on price, operational track record, LNG storage capacity, efficiency of the regasification process, vessel availability, size, age and condition and relationships with customers.
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Seasonality
Historically, LNG trade, and therefore charter rates, increased in the winter months and eased in the summer months as demand for LNG for heating in the Northern Hemisphere increased in colder weather and declined in warmer weather. In general, the LNG vessel industry, has become less dependent on the seasonal transport of LNG than it was 15 years ago. The advent of FSRUs has opened new markets and uses for LNG and has helped reduce the impact of seasonality. There is a higher seasonal demand during the summer months due to energy requirements for air conditioning in some markets or reduced availability of hydro power in others and a pronounced higher seasonal demand during the winter months for heating in other markets. There is however a tendency for a weaker vessel market in the periods between winter and summer.
Vessel Maintenance
Safety is our top priority. Our vessels are operated in a manner intended to protect the safety and health of our employees, the general public and the environment. We actively manage the risks inherent in our business and are committed to eliminating incidents that threaten safety, such as groundings, fires, spills and collisions. We are also committed to reducing emissions and waste generation. We have established key performance indicators to facilitate regular monitoring of our operational performance. As part of our ESG reporting we set targets to drive continuous improvement, and we review performance indicators frequently to determine if remedial action is necessary to reach our targets.
Under our charters, we are responsible for the technical management of the vessels which our subsidiaries and affiliates assist us by managing our vessel operations, maintaining a technical department to monitor and audit our vessel manager operations and providing expertise in various functions critical to our operations. This affords an efficient and cost effective operation and, pursuant to ship management and administrative services agreements with certain of our subsidiaries, access to human resources, financial and other administrative functions.
These functions are supported by on board and onshore systems for maintenance, inventory, purchasing and budget management. In addition, our day-to-day focus on cost control will be applied to our operations. To some extent, the uniform design of some of our vessels and the adoption of common equipment standards should also result in operational efficiencies, including with respect to crew training and vessel management, equipment operation and repairs, and spare parts requisition.
Risk of Loss, Insurance and Risk Management
The operation of any vessel, including LNG carriers, FSRUs and FLNGs has inherent risks. These risks include mechanical failure, personal injury, collision, property loss, vessel or cargo loss or damage and business interruption due to political circumstances in foreign countries and/or war risk situations or hostilities or pandemics. In addition, there is always an inherent possibility of marine disaster, including explosion, spills and other environmental mishaps, and the liabilities arising from owning and operating vessels in international trade. We believe that our present insurance coverage is adequate to protect us against the accident related risks involved in the conduct of our business and that we maintain appropriate levels of environmental damage and pollution insurance coverage consistent with standard industry practice. However, not all risks can be insured, and there can be no guarantee that any specific claim will be paid, or that we will always be able to obtain adequate insurance coverage at reasonable rates.
The Gimi, is currently undergoing conversion from a LNG carrier to a FLNG and is insured under a building risks policy arranged by the shipyard.
We have obtained hull and machinery insurance on all our vessels against marine and war risks, which include the risks of damage to our vessels, salvage or towing costs, and also insure against actual or constructive total loss of any of our vessels. However, our insurance policies contain deductible amounts for which we will be responsible. We have also arranged additional total loss coverage for each vessel. This coverage, which is called hull interest and freight interest coverage, provides us additional coverage in the event of the total loss of a vessel.
We have also obtained loss of hire insurance to protect us against loss of income in the event one of our vessels cannot be employed due to damage that is covered under the terms of our hull and machinery insurance. Under our loss of hire policies, our insurer will pay us the daily rate agreed in respect of each vessel for each day, in excess of a certain number of deductible days, for the time that the vessel is out of service as a result of damage. The maximum coverage varies from 120 days to 360 days, depending on the vessel. The number of deductible days varies from 30 days to 60 days, depending on the vessel and type of damage; (e.g. whether the claim arises from either machinery or hull damage).
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Protection and indemnity insurance, which covers our third-party legal liabilities in connection with our shipping activities, is provided by mutual protection and indemnity associations (“P&I clubs”). This includes third-party liability and other expenses related to the injury or death of crew members, passengers and other third-party persons, loss or damage to cargo, claims arising from collisions with other vessels or from contact with jetties or wharves and other damage to other third-party property, including pollution arising from oil or other substances, and other related costs, including wreck removal. Subject to the capping discussed below, our coverage, except for pollution, is unlimited.
The current protection and indemnity insurance coverage for pollution is $250 million per incident for the Hilli and $1 billion per vessel per incident for all other vessels. The thirteen P&I clubs that comprise the International Group of Protection and Indemnity Clubs insure approximately 90% of the world's commercial tonnage and have entered into a pooling agreement to reinsure each association's liabilities. Each P&I club has capped its exposure in this pooling agreement so that the maximum claim covered by the pool and its reinsurance would be approximately $8.2 billion per accident or occurrence. We are a member of Gard and Skuld P&I clubs. As a member of these P&I clubs, we are subject to a call for additional premiums based on the clubs' claims record, as well as the claims record of all other members of the P&I clubs comprising the International Group. However, our P&I clubs have reinsured the risk of additional premium calls to limit our additional exposure. This reinsurance is subject to a cap, and there is the risk that the full amount of the additional call would not be covered by this reinsurance.
The insurers providing the hull and machinery, hull and cargo interests, protection and indemnity and loss of hire insurances have confirmed that they will consider a FSRU as a vessel for the purpose of providing insurance. For the FSRU we have also arranged an additional comprehensive general liability insurance. This type of insurance is common for offshore operations and is additional to the P&I insurance.
Our operations utilize a thorough risk management program that includes, among other things, computer-aided risk analysis tools, maintenance and assessment programs, a seafarers' competence training program, seafarers' workshops and membership in emergency response organizations. We expect to benefit from our commitment to safety and environmental protection as certain of our subsidiaries, affiliates and service providers assists us in managing our vessel operations. Cool Company Management AS (formerly known as Golar Management Norway (“CCMN”), our former subsidiary and currently our service provider, received its ISO 9001 certification for a quality management system in April 2011, and is certified in accordance with the IMO's International Management Code for the Safe Operation of Ships and Pollution Prevention (the “ISM”), on a fully integrated basis.
Classification, Inspection and Maintenance
Every large, commercial seagoing vessel must be “classed” by a classification society. A classification society certifies that a vessel is “in class,” signifying that the vessel has been built and maintained in accordance with the rules of the vessel's country of registry and the international conventions of which that country is a member. In addition, where surveys are required by international conventions and corresponding laws and ordinances of a flag state, the classification society will undertake them on application or by official order, acting on behalf of the authorities concerned.
For maintenance of the class certificate, regular and extraordinary surveys of hull, machinery, including the electrical plant and any special equipment classed, are required to be performed by the classification society, to ensure continuing compliance. Most vessels are drydocked at least once during a five-year class cycle for inspection of the underwater parts and for repairs related to inspections. If any defects are found, the classification surveyor will issue a “recommendation” which must be rectified by the shipowner within prescribed time limits. The classification society also undertakes on request of the flag state other surveys and checks that are required by the regulations and requirements of that flag state. These surveys are subject to agreements made in each individual case and/or to the regulations of the country concerned.
All insurance underwriters make it a condition for insurance coverage that a vessel be certified as “in class” by a classification society, which is a member of the International Association of Classification Societies. Golar Arctic is certified by the American Bureau of Shipping. All of our other vessels are certified by Det Norske Veritas GL. Both societies are members of the International Association of Classification Societies. All of our vessels have been awarded ISM certification and are currently “in class” other than two vessels, the Gimi and the Gandria, with the Gimi in Keppel's shipyard in Singapore for her conversion into a FLNG, and the Gandria currently in lay up.
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We carry out inspections of the vessels on a regular basis; both at sea or while the vessels are in port or following COVID-19 restrictions, on a remote basis where applicable. The results of these inspections, which are conducted both in port and while underway, result in a report containing recommendations for improvements to the overall condition of the vessel, maintenance, safety and crew welfare. Based in part on these evaluations, we create and implement a program of continual maintenance and improvement for our vessels and their systems.
Environmental and Other Regulations
General
Our business and the operation of our vessels are subject to various international treaties and conventions and to the applicable local national and subnational laws and regulations of the countries in which our vessels operate or are registered. Such laws and regulations cover a variety of topics, including but not limited to air pollution, water pollution, waste management, protection of natural resources, and protection of worker health and safety, and might require us to obtain governmental permits and authorizations before we may conduct certain activities. Failure to comply with these laws or to obtain the necessary business and technical licenses could result in sanctions including suspension and/or freezing of the business and responsibility for all damages arising from any violation.
Governments may also periodically revise their environmental laws and regulations or adopt new ones, and the effects of new or revised laws and regulations on our operations cannot be predicted. Although we believe that we are substantially in compliance with applicable environmental laws and regulations and have all permits, licenses and certificates required for our vessels, future non-compliance or failure to maintain necessary permits or approvals could require us to incur substantial costs or temporarily suspend the operation of one or more of our vessels. There can be no assurance that additional significant costs and liabilities will not be incurred to comply with such current and future laws and regulations, or that such laws and regulations will not have a material effect on our operations. Similar or more stringent laws may also apply to our customers, including oil & gas exploration and production companies, which may impact demand for our services.
International environmental treaties and conventions as well as U.S. environmental laws and regulations that apply to the operation of our vessels are described below. Other countries, including member countries of the European Union, in which we operate or in which our vessels are registered have or may in the future have laws and regulations that are similar, or more stringent, in nature to the U.S. laws referenced below. CCMN provides technical management services for our vessels, is certified in accordance with the IMO standard for ISM and operates in compliance with the International Standards Organization (the “ISO”) Environmental Management Standard for the management of significant environmental aspects associated with the ownership and operation of our fleet.
International Maritime Regulations of LNG Vessels
The IMO provides international regulations governing shipping and international maritime trade. Among other requirements, the International Safety Management Code for the Safe Operation of Ships and for Pollution Prevention (“the ISM Code”) requires the party with operational control of a vessel to develop an extensive safety management system and the adoption of a policy for safety and environmental protection setting forth instructions and procedures for operating its vessels safely and also describing procedures for responding to emergencies. Our ship manager holds a document of compliance under the ISM Code for operation of Gas Carriers.
Vessels that transport gas, including LNG carriers and FSRUs, are also subject to regulation under the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (the “IGC Code”), published by the IMO. The IGC Code provides a standard for the safe carriage of LNG and certain other liquid gases by prescribing the design and construction standards of vessels involved in such carriage. The completely revised and updated IGC Code entered into force in 2016, and the amendments were developed following a comprehensive five-year review and are intended to take into account the latest advances in science and technology. Compliance with the IGC Code must be evidenced by a Certificate of Fitness for the Carriage of Liquefied Gases in Bulk. Each of our vessels is in compliance with the IGC Code and each of our new buildings/conversion contracts requires that the vessel receive certification that it is in compliance with applicable regulations before it is delivered.
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The IMO also promulgates ongoing amendments to the International Convention for the Safety of Life at Sea (“SOLAS”), which provides rules for the construction of and equipment required for commercial vessels and includes regulations for safe operation and addresses maritime security. SOLAS requires, among other things, the provision and maintenance of lifeboats and other life-saving appliances, requires the use of the Global Maritime Distress and Safety System (an international radio equipment and watch keeping standard), afloat and at shore stations, and relates to the International Convention on the Standards of Training and Certification of Watchkeeping Officers (“STCW”) also promulgated by the IMO. The STCW establishes minimum training, certification, and watchkeeping standards for seafarers. The SOLAS and other IMO regulations concerning safety, including those relating to treaties on training of shipboard personnel, lifesaving appliances, radio equipment and the global maritime distress and safety system, are applicable to our operations. Flag states that have ratified the SOLAS and STCW generally employ the classification societies, which have incorporated the SOLAS and STCW requirements into their class rules, to undertake surveys to confirm compliance.
In the wake of increased worldwide security concerns, the IMO amended SOLAS and added the International Ship and Port Facility Security Code (“ISPS Code”), which came into effect on July 1, 2004, to detect security threats and take preventive measures against security incidents affecting vessels or port facilities. CCMN has developed security plans and appointed and trained ship and office security officers. In addition, all of our vessels have been certified to meet the ISPS Code and the security requirements of the SOLAS and the Maritime Transportation Security Act (“MTSA”).
The IMO continues to review and introduce new regulations. It is impossible to predict what additional regulations, if any, may be passed by the IMO and what effect, if any, such regulation may have on our operations. Non-compliance with the IGC Code or other applicable IMO regulations may subject a shipowner or a bareboat charterer to increased liability or penalties, may lead to decreases in available insurance coverage for affected vessels and may result in the denial of access to, or detention in, some ports.
Air Emissions
The IMO adopted MARPOL, which imposes environmental standards on the shipping industry relating to marine pollution, including oil spills, management of garbage, the handling and disposal of noxious liquids, sewage and air emissions. MARPOL is broken into six Annexes, each of which regulates a different source of pollution. Annex I relates to oil leakage or spilling and applies to various vessels delivered on or after August 1, 2010. It includes requirements for the protected location of the fuel tanks, performance standards for accidental oil fuel outflow, a tank capacity limit and certain other maintenance, inspection and engineering standards. IMO regulations also require owners and operators of vessels to adopt Shipboard Oil Pollution Emergency Plans. Periodic training and drills for response personnel and for vessels and their crews are required. Annexes II and III relate to harmful substances carried in bulk, in liquid or in packaged form, respectively, and Annexes IV and V relate to sewage and garbage management, respectively.
MARPOL 73/78 Annex VI regulations for the “Prevention of Air Pollution from Ships” apply to all vessels, fixed and floating drilling rigs and other floating platforms. Annex VI sets limits on sulfur oxide and nitrogen oxide emissions from vessel exhausts, emissions of volatile compounds from cargo tanks, incineration of specific substances, and prohibits deliberate emissions of ozone depleting substances. Annex VI also includes a global cap on sulfur content of fuel oil and allows for special areas to be established with more stringent controls on sulfur emissions. The certification requirements for Annex VI depend on size of the vessel and time of the periodic classification survey. Ships weighing more than 400 gross tons and engaged in international voyages involving countries that have ratified the conventions, or vessels flying the flag of those countries, are required to have an International Air Pollution Certificate (“IAPP Certificate”). Annex VI came into force in the United States on January 8, 2009. All our vessels delivered or drydocked since May 19, 2005 have been issued IAPP Certificates.
Amendments to Annex VI to the MARPOL Convention that took effect in 2010 imposed progressively stricter limitations on sulfur emissions from vessels. As of January 1, 2020, the ultimate limit of 0.5% allowable sulfur content for fuel used to power vessels operating in areas outside of designated emission control areas (“ECAs”) took effect. This represents a substantial reduction from the previous 3.5% sulfur cap. The 0.5% sulfur cap is generally referred to as IMO 2020 and applies absent the installation of expensive sulfur scrubbers to meet reduced emission requirements for sulfur. Our vessels have achieved compliance with sulfur emission standards, where necessary, by being modified to burn gas only in their boilers when alongside a berth. The amendments to Annex VI also established new tiers of stringent nitrogen oxide emissions standards for new diesel engines, depending on their date of installation. The European directive 2005/33/EC bans the use of fuel oils containing more than 0.10% sulfur by mass by any merchant vessel while at berth in any EU country.
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Even more stringent sulfur emission standards apply in coastal areas designated as ECAs, such as the United States and Canadian coastal areas designated by the IMO's Marine Environment Protection Committee (“MEPC”), as discussed in the “U.S. Clean Air Act” below. These areas include certain coastal areas of North America and the United States Caribbean Sea. Annex VI Regulation 14, which came into effect on January 1, 2015, set a 0.10% sulfur limit in areas of the Baltic Sea, North Sea, North America, and United States Caribbean Sea ECAs.
U.S. air emissions standards are now equivalent to these amended Annex VI requirements. Additional or new conventions, laws and regulations may be adopted that could require the installation of expensive emission control systems. Because our vessels are largely powered by means other than fuel oil we do not anticipate that any emission limits that may be promulgated will require us to incur any material costs for the operation of our vessels, but that possibility cannot be eliminated.
Clean Air Act
The U.S. Clean Air Act of 1970 (including its amendments of 1977 and 1990) (“CAA”) requires the Environmental Protection Agency (the “EPA”) to promulgate standards applicable to emissions of volatile organic compounds and other air contaminants. Our vessels are subject to vapor control and recovery requirements for certain cargos when loading, unloading, ballasting, cleaning and conducting other operations in regulated port areas and emission standards for so-called “Category 3” marine diesel engines operating in U.S. waters. The marine diesel engine emission standards are currently limited to new engines beginning with the 2004 model year. On April 30, 2010, the EPA promulgated final emission standards for Category 3 marine diesel engines equivalent to those adopted in the amendments to Annex VI to MARPOL. The emission standards apply in two stages: near-term standards for newly-built engines apply from 2011, and long-term standards requiring an 80% reduction in nitrogen dioxides, or NOx, apply from 2016. A further stage of reductions, known as “Tier 4” standards, has also been developed and implemented. However, in October 2020, EPA published a final rule to provide additional lead time for implementation for certain high-speed vessels. Pursuant to the final rule, the Tier 4 standards apply from model year 2022 for engines installed in a wide range of high-speed vessels, and from model year 2024 for engines installed in certain other such vessels, subject to certain limitations. Separately, in December 2019, the EPA published a final rule concerning national diesel fuel regulations that will allow fuel suppliers to distribute distillate diesel fuel that complies with the 0.5% international sulfur cap instead of fuel standards that otherwise apply to distillate diesel fuel in the United States. Fuel that does not meet the 0.5% sulfur cap cannot be used in ECA boundaries. Compliance with these standards may cause us to incur costs to install control equipment on our vessels in the future.
Anti-Fouling Requirements
Anti-fouling systems, such as paint or surface treatment, are used to coat the bottom of vessels to prevent the attachment of mollusks and other sea life to the hulls of vessels. Our vessels are subject to the IMO’s International Convention on the Control of Harmful Anti-fouling Systems on Ships, or the “Anti-fouling Convention”, which prohibits the use of organotin compound coatings in anti-fouling systems. Vessels of over 400 gross tons engaged in international voyages must obtain an International Anti-fouling System Certificate and undergo an initial survey before the vessel is put into service or when the anti-fouling systems are altered or replaced. In November 2020, MEPC 75 approved draft amendments to the Anti-fouling Convention to prohibit anti-fouling systems containing cybutryne, which would apply to ships from January 1, 2023, or, for ships already bearing such an anti-fouling system, at the next scheduled renewal of the system after that date, but no later than 60 months following the last application to the ship of such a system. These amendments were formally adopted at MEPC 76 in June 2021. We have obtained Anti-fouling System Certificates for all of our vessels, and we do not believe that maintaining such certificates will have an adverse financial impact on the operation of our vessels.
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Oil Pollution Act and The Comprehensive Environmental Response Compensation and Liability Act
The U.S. Oil Pollution Act of 1990 (“OPA”) established an extensive regulatory and liability regime for the protection and cleanup of the environment from oil spills. OPA affects all owners and operators whose vessels trade or operate within the U.S., its territories and possessions, or whose vessels operate in the waters of the U.S., which includes the U.S. territorial seas and its 200 nautical mile exclusive economic zone. The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), which applies to the discharge of hazardous substances whether on land or at sea. While OPA and CERCLA would not apply to the discharge of LNG, these laws may affect us because we carry oil as fuel and lubricants for our engines, and the discharge of these could cause an environmental hazard. Under OPA, vessel owners and operators, are “responsible parties” and are jointly, severally and strictly liable (unless the spill results solely from the act or omission of a third party, an act of God or an act of war) for all containment and clean-up costs and other damages arising from discharges or threatened discharges of oil from their vessels, including bunkers (fuel). OPA defines these damages broadly to include:
•injury to, destruction or loss of, or loss of use of, natural resources and related assessment costs;
•injury to, or economic losses resulting from, the destruction of real and personal property;
•net loss of taxes, royalties, rents, fees or net profit revenues resulting from injury, destruction or loss of real or personal property, or natural resources;
•loss of subsistence use of natural resources that are injured, destroyed or lost;
•lost profits or impairment of earning capacity due to injury, destruction or loss of real or personal property or natural resources; and
•net cost of increased or additional public services necessitated by removal activities following a discharge of oil, such as protection from fire, safety or health hazards.
The limits of OPA liability are the greater of $2,300 per gross ton or $19,943,400 for any tanker other than single-hull tank vessels, over 3,000 gross tons (subject to possible adjustment for inflation). These limits of liability do not apply, however, where the incident is caused by violation of applicable U.S. federal safety, construction or operating regulations, or by the responsible party's gross negligence or willful misconduct. These limits likewise do not apply if the responsible party fails or refuses to report the incident or to cooperate and assist in connection with the substance removal activities. OPA specifically permits individual states to impose their own liability regimes with regard to oil pollution incidents occurring within their boundaries, and some states have enacted legislation providing for unlimited liability for discharge of pollutants within their waters. In some cases, states, which have enacted their own legislation, have not yet issued implementing regulations defining ship owners’ responsibilities under these laws.
CERCLA, which also applies to owners and operators of vessels, contains a similar liability regime and provides for recovery of clean up and removal costs and the imposition of natural resource damages for releases of “hazardous substances,” which as defined in CERCLA does not include oil. Liability under CERCLA is limited to the greater of $300 per gross ton or $0.5 million for each release from vessels not carrying hazardous substances as cargo or residue, and the greater of $300 per gross ton or $5 million for each release from vessels carrying hazardous substances as cargo or residue. As with OPA, these limits of liability do not apply where the incident is caused by violation of applicable U.S. federal safety, construction or operating regulations, or by the responsible party's gross negligence or willful misconduct or if the responsible party fails or refuses to report the incident or to cooperate and assist in connection with the substance removal activities. OPA and CERCLA each preserve the right to recover damages under existing law, including maritime tort law. We believe that we are in substantial compliance with OPA, CERCLA and all applicable state regulations in the ports where our vessels call.
OPA and CERCLA both require owners and operators of vessels to establish and maintain with the USCG evidence of financial responsibility sufficient to meet the maximum amount of liability to which the particular responsible person may be subject. Vessel owners and operators may satisfy their financial responsibility obligations by providing a proof of insurance, a surety bond, qualification as a self-insurer or a guaranty. Under OPA regulations, an owner or operator of more than one vessel is required to demonstrate evidence of financial responsibility for the entire fleet in an amount equal only to the financial responsibility requirement of the vessel having the greatest maximum liability under OPA/CERCLA. Each of our ship owning subsidiaries and affiliates that has vessels trading in U.S. waters has applied for and obtained from the U.S. Coast Guard National Pollution Funds Center three-year certificates of financial responsibility, or COFRs, supported by guarantees purchased from an insurance based provider. We believe that we will be able to continue to obtain the requisite guarantees and that we will continue to be granted COFRs from the U.S. Coast Guard for each of our vessels that is required to have one.
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Compliance with any new requirements of OPA and future legislation or regulations applicable to the operation of our vessels could impact the cost of our operations and adversely affect our business and ability to make distributions to our shareholders. We currently maintain pollution liability coverage insurance in the amount of $1 billion per incident for each of our vessels. If the damages from a catastrophic spill were to exceed our insurance coverage it could have an adverse effect on our business and results of operation.
Bunker Convention/CLC State Certificate
The International Convention on Civil Liability for Bunker Oil Pollution 2001, (“the Bunker Convention”), entered into force on November 21, 2008. The Bunker Convention provides a liability, compensation and compulsory insurance system for the victims of oil pollution damage caused by spills of bunker oil. The Bunker Convention imposes strict liability on ship owners (including the registered owner, bareboat charterer, manager or operator) for pollution damage in jurisdictional waters of ratifying states caused by discharges of bunker fuel. Registered owners of any sea going vessel and seaborne craft over 1,000 gross tonnage, of any type whatsoever, and registered in a State Party, or entering or leaving a port in the territory of a State Party, will be required to maintain insurance which meets the requirements of the Bunker Convention and to obtain a certificate issued by a State Party attesting that such insurance is in force. The State Party issued certificate must be carried on board at all times. P&I Clubs in the International Group issue the required Bunker Convention “Blue Cards” provide evidence that there is insurance in place that meets the Bunker Convention requirements and thereby enable signatory states to issue certificates. All of our vessels have received “Blue Cards” from their P&I Club and are in possession of a Civil Liability Convention (CLC) State-issued certificate attesting that the required insurance cover is in force.
Ballast Water Management Convention, Clean Water Act and National Invasive Species Act
The IMO has negotiated international conventions that impose liability for pollution in international waters and the territorial waters of the signatories to such conventions. The EPA and USCG, have also enacted rules relating to ballast water discharge for all vessels entering or operating in United States waters. Compliance requires the installation of equipment on our vessels to treat ballast water before it is discharged or the implementation of other port facility disposal arrangements or procedures at potentially substantial cost, and/or otherwise restrict our vessels from entering United States waters.
a. Ballast Water Management Convention
In February 2004, the IMO adopted an International Convention for the Control and Management of Ships' Ballast Water and Sediments (the “BWM Convention”). The BWM Convention's implementing regulations call for a phased introduction of mandatory ballast water exchange requirements to be replaced in time with mandatory concentration limits. As of December 31, 2021, all our operational LNG carriers and FSRU had installed ballast water treatment systems.
b. Clean Water Act
The U.S. Clean Water Act (the “CWA”) prohibits the discharge of oil, hazardous substances and ballast water in U.S. navigable waters unless authorized by a duly-issued permit or exemption, and imposes strict liability in the form of penalties for any unauthorized discharges. The CWA also imposes substantial liability for the costs of removal, remediation and damages and complements the remedies available under OPA and CERCLA. In addition, many U.S. states that border a navigable waterway have enacted environmental pollution laws that impose strict liability on a person for removal costs and damages resulting from a discharge of oil or a release of a hazardous substance. These laws may be more stringent than U.S. federal law.
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The EPA regulates the discharge of ballast and bilge water and other substances in United States waters under the CWA. The EPA regulations historically have required vessels 79 feet in length or longer (other than commercial fishing vessels and recreational vessels) to obtain and comply with a permit that regulates ballast water discharges and other discharges incidental to the normal operation of certain vessels within United States waters. In March 2013, the EPA issued the Vessel General Permit for Discharges Incidental to the Normal Operation of Vessels, (“VGP”). The 2013 VGP focuses on authorizing discharges incidental to operations of commercial vessels and contains ballast water discharge limits for most vessels to reduce the risk of invasive species in US waters, more stringent requirements for exhaust gas scrubbers and the use of environmentally acceptable lubricants. In December 2018, the Vessel Incidental Discharge Act (“VIDA”) was signed into law and restructured the EPA and the USCG programs for regulating incidental discharges from vessels. Rather than requiring CWA permits, the discharges will be regulated under a new CWA Section 312(p) establishing Uniform National Standards for Discharges Incidental to Normal Operation of Vessels. Under VIDA, VGP provisions and existing USCG regulations will be phased out over a period of approximately four years and replaced with National Standards of Performance (“NSPs”) to be developed by EPA and implemented and enforced by the USCG. Under VIDA, the EPA was directed to develop the NSPs by December 2020 and the USCG is directed to develop its corresponding regulations two years after EPA develops the NSPs. On October 26, 2020, EPA issued proposed regulations to establish NSPs, including general discharge standards of performance, covering general operation and maintenance, biofouling management, and oil management, and specific discharge standards applicable to specified pieces of equipment and systems. The 2013 VGP was scheduled to expire in December 2018, however, under VIDA the provisions of the 2013 VGP will remain in place until the new EPA and USCG regulations are in place, which remain outstanding. Pursuant to the requirements in the VGP, vessel owners and operators must meet twenty-five sets of state-specific requirements as the CWA’s 401 certification process allows tribes and states to impose their own requirements for vessels operating within their waters. Vessels operating in multiple jurisdictions could face potentially conflicting conditions specific to each jurisdiction that they travel through.
c. National Invasive Species Act
The USCG regulations adopted under the U.S. National Invasive Species Act (“NISA”) require the USCG's approval of any technology before it is placed on a vessel. As a result, the USCG has provided waivers to vessels which could not install the then as-yet unapproved technology. In May 2016, the USCG published a review of the practicability of implementing a more stringent ballast water discharge standard. The results concluded that technology to achieve a significant improvement in ballast water treatment efficacy cannot be practically implemented. In February 2016, the USCG issued a new rule amending the Coast Guard’s ballast water management record-keeping requirements. Effective February 22, 2016, vessels with ballast tanks operating exclusively on voyages between ports or places within a single Captain of the Port zone were required to submit an annual report of their ballast water management practices. Further, under the amended requirements, vessels may submit their reports after arrival at the port of destination instead of prior to arrival. As discussed above, under VIDA, existing USCG ballast water management regulations will be phased out over a period of approximately four years and replaced with NSPs to be developed by EPA and implemented and enforced by the USCG.
European Union Regulations
In October 2009, the European Union amended a directive to impose criminal sanctions for illicit ship-source discharges of polluting substances, including minor discharges, if committed with intent, recklessly or with serious negligence and the discharges individually or in the aggregate result in deterioration of the quality of water. Aiding and abetting the discharge of a polluting substance may also lead to criminal penalties. The directive applies to all types of vessels, irrespective of their flag, but certain exceptions apply to warships or where human safety or that of the ship is in danger. Criminal liability for pollution may result in substantial penalties or fines and increased civil liability claims. Regulation (EU) 2015/757 of the European Parliament and of the Council of 29 April 2015 (amending EU Directive 2009/16/EC) governs the monitoring, reporting and verification of carbon dioxide emissions from maritime transport, and, subject to some exclusions, requires companies with ships over 5,000 gross tonnage to monitor and report carbon dioxide emissions annually, which may cause us to incur additional expenses.
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The European Union has adopted several regulations and directives requiring, among other things, more frequent inspections of high-risk ships, as determined by type, age and flag as well as the number of times the ship has been detained. The European Union also adopted and extended a ban on substandard ships and enacted a minimum ban period and a definitive ban for repeated offenses. The regulation also provided the European Union with greater authority and control over classification societies, by imposing more requirements on classification societies and providing for fines or penalty payments for organizations that failed to comply. Furthermore, the EU has implemented regulations requiring vessels to use reduced sulfur content fuel for their main and auxiliary engines. The EU Directive 2005/33/EC (amending Directive 1999/32/EC) introduced requirements parallel to those in Annex VI relating to the sulfur content of marine fuels. In addition, the EU imposed a 0.1% maximum sulfur requirement for fuel used by ships at berth in the Baltic, the North Sea and the English Channel (the so called “SOx-Emission Control Area”). As of January 2020, EU member states must also ensure that ships in all EU waters, except the SOx-Emission Control Area, use fuels with a 0.5% maximum sulfur content.
International Labour Organization
The International Labour Organization (the “ILO”) is a specialized agency of the UN that has adopted the Maritime Labor Convention 2006 (“MLC 2006”). A Maritime Labor Certificate and a Declaration of Maritime Labor Compliance is required to ensure compliance with the MLC 2006 for all ships that are 500 gross tonnage or over and are either engaged in international voyages or flying the flag of a Member and operating from a port, or between ports, in another country. We believe that all our vessels are in substantial compliance with and are certified to meet MLC 2006.
Greenhouse Gas (“GHG”) Regulation
The issue of climate change and the effect of GHG emissions, in particular emissions from fossil fuels, has and continues to attract attention from a wide range of groups, including politicians, regulators, financial institutions, and the general public.
Currently, emissions of GHGs from international shipping are not subject to the international protocols and agreements addressing climate change, such as the 2005 Kyoto Protocol and the 2015 Paris Agreement. However, absent a global approach to address GHG emissions from international transport, the European Union has initiated action and is pursuing a strategy to integrate maritime emissions into the overall European Union strategy to reduce GHG emissions. In 2013, the European Commission initiated a three-step strategy aimed at this reduction consisting of (i) monitoring, reporting and verification of carbon dioxide emissions from large vessels using European Union ports, (ii) establishment of GHG reduction targets for sector; and (iii) implementation of further measures, including market-based measures such an emissions trading, in the medium to long term. EU Directive 2018/410, which amended the EU Emissions Trading System Directive, emphasized the need to act on GHG emissions from shipping and other sectors and called for action by either IMO or the European Union to address emissions from the international transport sector from 2023. The first step of the three-step strategy initiated in 2013 was addressed with a European Union regulation that took effect in January 2018 that requires large vessels (over 5,000 gross tons) calling at European ports to collect and publish data on carbon dioxide emissions and other information. On September 15, 2020, the European Parliament approved draft legislation, which has not yet been finalized, that would include GHG emissions from large vessels in the EU emissions trading system as of January 1, 2022 and include methane emissions in monitoring, reporting and verification requirements applicable to vessels. The European Parliament has also called for binding carbon dioxide reduction targets for shipping companies, which would require reduction of annual average carbon dioxide emissions of all ships during operation by at least 40% relative to 2008 levels, by 2030, and apply even deeper cuts by 2050.
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In addition, the IMO has taken some action, including mandatory measures to reduce emissions of GHGs from all vessels that took effect in January 2013. These measures included amendments to MARPOL Annex VI Regulations requiring the Energy Efficiency Design Index (“EEDI”) for new vessels, and the Ship Energy Efficiency Management Plan (“SEEMP”) for all vessels. The regulations apply to all vessels of 400 gross tonnage and above. The IMO also adopted a mandatory requirement in October 2016, which entered into force in March 2018, that ships of 5,000 gross tonnage and above record and report their fuel oil consumption, with the first year of data collection having commenced on January 1, 2019. These measures affect the operations of vessels that are registered in countries that are signatories to MARPOL Annex VI or vessels that call upon ports located within such countries. MEPC subsequently adopted further amendments to MARPOL Annex VI intended to significantly strengthen the EEDI “phase 3” requirements. These amendments accelerate the entry into effect date of phase 3 from 2025 to 2022 for several ship types, including gas carriers, general cargo ships and LNG carriers and require new ships built from that date to be significantly more energy efficient. The MEPC also is looking into the possible introduction of a phase 4 of EEDI requirements. The implementation of the EEDI and SEEMP standards could cause us to incur additional compliance costs. The IMO is also considering the implementation of a market-based mechanism for greenhouse gas emissions from vessels. The IMO adopted its initial GHG reduction strategy in 2018 and established a program of follow-up actions up to 2023 as a planning tool. (“IMO GHG Strategy”). The IMO GHG Strategy has established a goal of a reduction in carbon intensity of international shipping by at least 40% by 2030 compared to 2008, and by at least 50% by 2050 compared to 2008.
In November 2020, the MEPC agreed to draft amendments to MARPOL Annex VI establishing an enforceable regulatory framework to reduce GHG emissions from international shipping, consisting of technical and operational carbon reduction measures. These measures include use of an Energy Efficiency Existing Ship Index (“EEXI”), an operational Carbon Intensity Indicator (“CII”) and an enhanced SEEMP to drive carbon intensity reductions. A vessel’s attained EEXI would be calculated in accordance with values established based on type and size category, which compares the vessels’ energy efficiency to a baseline. A vessel would then be required to meet a specific EEXI based on a required reduction factor expressed as a percentage relative to the EEDI baseline. Under the draft MARPOL VI amendments, vessels with a gross tonnage of 5,000 or greater must determine their required annual operational CII and their annual carbon intensity reduction factor needed to ensure continuous improvement of the vessel’s CII. On an annual basis, the actual annual operational CII achieved would be documented and verified against the vessel’s required annual operational CII to determine the vessel’s operational carbon intensity rating on a performance level scale of A (major superior) to E (inferior). The performance level would be required to be recorded in the vessel’s SEEMP. A vessel with an E rating, or three consecutive years of a D (minor inferior) rating, would be required to submit a corrective action plan showing how the vessel would achieve a C (moderate) or above rating. This regulatory approach is expected to be consistent with the IMO GHG Strategy target of a 40% carbon intensity reduction for international shipping by 2030, as compared to 2008. MEPC adopted these amendments to MARPOL Annex VI in June 2021 and are expected to enter into force by November 2022, with the requirements for EEXI and CII certification coming into effect January 2023. At the same meeting, MEPC announced plans to revise the IMO GHG Strategy to establish stronger targets, with an aim to adoption of a revised strategy at the MEPC meeting in Spring 2023.
An increasing number of financial institutions have also established policies or commitments to reduce emissions associated with their portfolios. In 2019, a consortium of shipping financiers launched the Poseidon Principles, a framework to assess and disclose the alignment of ship finance portfolios with the climate-related goals of the IMO. While voluntary, signatories commit to implementing the Poseidon Principles in their internal policies. Similarly, at the 26th Conference to the Parties of the United Nations Framework Convention on Climate Change (“COP 26”), the Glasgow Financial Alliance for Net Zero (“GFANZ”) announced that commitments from over 450 firms across 45 countries had resulted in over $130 trillion in capital committed to net zero goals. The various sub-alliances of GFANZ generally require participants to set short-term, sector-specific targets to transition their financing, investing, and/or underwriting activities to net zero emissions by 2050. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. In late 2020, the Federal Reserve announced that it had joined the Network for Greening the Financial System, a consortium of financial regulators focused on addressing climate-related risks in the financial sector. Subsequently, the Federal Reserve has issued a statement in support of the efforts of the NGFS to identify key issues and potential solutions for the climate-related challenges most relevant to central banks and supervisory authorities. Limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development, production, liquefaction, or related activities, which may ultimately reduce demand for our services. Additionally, the Securities and Exchange Commission announced its intention to promulgate rules requiring climate disclosures. Although the form and substance of these requirements is not yet known, this may result in additional costs to comply with any such disclosure requirements.
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In the U.S., the EPA issued a finding that GHGs endanger public health and safety and has adopted regulations that regulate the emission of GHGs from certain sources. For example, fossil fuel companies to whom we provide services are subject to regulations by various government agencies, which may include the EPA and bodies within the Department of the Interior (“DOI”). These regulations may include restrictions on certain oil & gas production or stimulation techniques, requirements for the installation and use of certain emissions control technologies, and other regulations that may adversely impact the operations of our customers, which may ultimately reduce demand for our services. Regarding our own operations, the EPA enforces both the CAA and the international standards found in Annex VI of MARPOL concerning marine diesel emissions, and the sulfur content found in marine fuel. Other federal and state regulations relating to the control of greenhouse gas emissions may follow, including climate change initiatives that have been considered in the U.S. Congress. Notably, the U.S. rejoined the Paris Agreement in February 2021, and, in April 2021, announced a new, more rigorous nationally determined emissions reduction level of 50-52% reduction from 2005 levels in economy-wide net GHG emissions by 2030. At the international level, at COP 26, the U.S. and European Union jointly announced the launch of the Global Methane Pledge, an initiative committing to a collective goal of reducing global methane emissions by at least 30% from 2020 levels by 2030, including “all feasible reductions” in the energy sector.
Any passage of climate control legislation or other regulatory or policy initiatives by the IMO, the European Union, the United States, or other countries where we operate, or any treaty adopted at the international level that restricts emissions of GHGs from vessels, could require us to make significant financial expenditures that we cannot predict with certainty at this time. In addition, even without such regulation, our business may be indirectly affected to the extent that climate change results in sea level changes or more intense weather events.
Other Regulations
Our LNG vessels may also become subject to the International Convention on Liability and Compensation for Damage in Connection with the Carriage of Hazardous and Noxious Substances by Sea, or HNS, adopted in 1996, the HNS Convention, and subsequently amended by the April 2010 Protocol. The HNS Convention creates a regime of liability and compensation for damage from hazardous and noxious substances, including liquefied gases. The HNS Convention introduces strict liability for the ship owner and covers pollution damage as well as the risks of fire and explosion, including loss of life or personal injury and damage to property. At least 12 states must ratify or accede to the 2010 Protocol for it to enter into effect. In July 2019, South Africa became the 5 th state to ratify the protocol. At least 7 more states must ratify or accede to the treaty for it to enter into effect.
The April 2010 Protocol sets up a two-tier system of compensation composed of compulsory insurance taken out by ship owners and an HNS fund that comes into play when the insurance is insufficient to satisfy a claim or does not cover the incident. Under the 2010 Protocol, if damage is caused by bulk HNS, claims for compensation will first be sought from the ship owner up to a maximum of 100 million Special Drawing Rights, or SDR. SDR is a potential claim on the freely usable currencies of the IMF members. If the damage is caused by packaged HNS or by both bulk and packaged HNS, the maximum liability is 115 million SDR. Once the limit is reached, compensation will be paid from the HNS Fund up to a maximum of 250 million SDR. We cannot estimate the costs that may be needed to comply with any such requirements that may be adopted with any certainty at this time.
C. Organizational Structure
For a list of our significant subsidiaries, please see Exhibit 8.1 to this annual report and note 4 “Subsidiaries” of our consolidated financial statements included herein. All of our subsidiaries are, directly or indirectly, wholly-owned by us except for Hilli LLC, Hilli Corp and Gimi MS Corporation (“Gimi MS”).
D. Property, Plant and Equipment
For information on our fleet, please see the section of this item entitled “Vessel Operations”.
We do not own any interest in real estate. As of December 31, 2021, we lease approximately 10,700 square feet of office space in London and approximately 32,000 square feet of office space in Oslo. For our ship management operations, we lease approximately 4,200 square feet of office space in Malaysia, approximately 5,500 square feet of office space in Croatia, approximately 2,500 square feet of office space in Bermuda and approximately 2,100 square feet of office space in Cameroon.
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ITEM 4A. UNRESOLVED STAFF COMMENTS
None.
ITEM 5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS
The following discussion of our financial condition and results of operations should be read in conjunction with the sections of this Annual Report entitled “Item 4. Information on the Company” and our audited financial statements and notes thereto, included herein. Our financial statements have been prepared in accordance with U.S. GAAP. This discussion includes forward-looking statements based on assumptions about our future business. You should also review the section of this Annual Report entitled “Cautionary Statement Regarding Forward-Looking Statements” and “Item 3. Key Information - D. Risk Factors” for a discussion of important factors that could cause our actual results to differ materially from the results described in or implied by certain forward-looking statements.
Significant Developments in Early 2022
Financings
(i) 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.
(ii) Corporate bilateral facility
In February 2022, Golar LNG executed a $250 million corporate bilateral facility with Sequoia Investment Management secured by our shareholding in FLNG Hilli and Gimi. The corporate bilateral facility has a tenor of 7-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. The corporate bilateral facility remained undrawn as of April 14, 2022 and will remain available for drawdown until 30 June 2022.
(iii) Norwegian Bonds
In October 2021, we placed $300 million in senior unsecured bonds carrying a fixed coupon of 7% in the Nordic bond market (the “Norwegian Bonds”). In March 2022, we subsequently listed the Norwegian bonds on the Oslo Børs.
(iv) Share buyback
In March 2022, we repurchased 368,496 shares in Golar LNG, as part of our share repurchase program, at a total cost of $6.6 million, inclusive of related fees. These shares were subsequently cancelled in March 31, 2022, reducing the balance of issued and outstanding common shares.
(v) Sale of NFE common stock
In April 2022, we sold 6.2 million shares of our NFE common stock raising net proceeds of $253.0 million. We plan to use these proceeds to deploy FLNG growth projects and general corporate purposes. Following the sale of such shares, our remaining holdings in NFE common stock is 12.4 million.
UK tax lease benefits
In April 2022, we settled and paid in full, the UK HMRC, our liability in relation to past tax leases, amounting to $63.5 million, of which $16.0 million was funded from our restricted cash. The first priority security interest on the Gandria and the second priority security interests on the Golar Tundra and Golar Frost were also released.
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Completion of the sale of eight TFDE LNG vessels to Cool Co
On January 26, 2022, we and Cool Co, our wholly owned subsidiary, entered into the Vessel SPA under which Cool Co will acquire eight modern TFDE LNG vessels and the Cool Pool Limited, the fleet's commercial management company, from us. The purchase price for each vessel was agreed at $145.0 million, subject to working capital and debt adjustments. Following completion of the transactions contemplated under the Vessel SPA in April 2022, we now own 31.3% interest in Cool Co. The existing sale and leaseback loans, except for the loans secured over the Golar Ice and Golar Kelvin which will be assumed by Cool Co, were refinanced in connection with the closing of the Vessel SPA and were contemporaneously deconsolidated from our financial statements. Post completion of the transactions contemplated under the Vessel SPA, we will continue to be the guarantor to the Golar Ice and Golar Kelvin sale and leaseback arrangements. Subject to certain adjustments which include but are not limited to net debt and working capital at the date of deconsolidation, the indicative book loss on disposal is estimated at $200 - $250 million.
Factors Affecting Our Future Results of Operations and Financial Condition
Our historical results of operations and cash flows may not be indicative of our future results of operations which may be principally affected for the following reasons:
•A decline in NFE's share price may adversely affect our business. On April 15, 2021, upon the closing of the Hygo Merger, we received 18.6 million shares of NFE common stock valued at $44.65 per share and subsequent to our sale of 6.2 million shares of NFE common stock in April 2022, we now hold 12.4 million shares. Our future results of operations are therefore exposed to the volatility of NFE's share price. Subsequent to the Hygo Merger, the price of NFE common shares has fluctuated significantly, reaching a low of $19.17 per share in February 2022 and recovering to $48.29 in April 2022. Should the price of NFE common shares fall materially, our cash flows, financial condition and results of operations could be adversely affected.
•Operation and maintenance of external vessels. In December 2020, the LNG Croatia was accepted by LNG Hrvatska, its customer, following her conversion to a FSRU. Under the O&M Agreement, we will operate and maintain the LNG Croatia for a minimum period of 10 years, effective January 1, 2021. Should we be unable to meet our obligations under the O&M agreement, we could be obligated to pay damages to LNG Hrvatska which could have a negative impact on our earnings and cash flow and harm our reputation.
•Conversion of the Gimi. FLNG Gimi conversion project is 82% technically complete as of April 14, 2022. The FLNG conversion requires highly specialized contractors and is subject to risk of delay or default by shipyard or other factors outside our or the shipyard's control such as COVID-19. In the event the shipyard does not perform under the terms of the agreement and we are unable to enforce certain refund guarantees with third party banks, we may lose part or all of our investment, breach certain bank covenants which will obligate us to repay the outstanding debt principal and associated interest and penalties and harm our reputation as a FLNG company.
•Utilization of the Hilli's full capacity. In July 2021, we signed an agreement with the Customer to increase the utilization of Hilli (“the Hilli Extended Capacity Agreement”). Commencing in January 2022, the capacity utilization of Hilli will increase by 0.2 million tons of LNG, bringing total utilization in 2022 to 1.4 million tons (“2022 Incremental Capacity”). Under the Hilli Extended Capacity Agreement, we also granted the Customer an option to increase the capacity utilization of Hilli by up to 0.4 million tons of LNG per year from January 1, 2023 through to the end of the current contract term in July 2026, which must be declared by the Customer during the third quarter of 2022 (“2023 Incremental Capacity”). Should the option for the 2023 Incremental Capacity not be exercised, this could adversely affect our plans to realize the full potential of this asset and maximize return on our investment.
•Our results are dependent on the performance of our equity method investments. Given our substantial investments in Cool Co and Avenir, adverse net results from these investees could affect our earnings which may eventually negatively impact the price of our common shares.
•Our results are affected by fluctuations in the fair value of our derivative instruments. The change in fair value of our derivative instruments is included in our net income. These changes may fluctuate significantly as interest rates, the price of our common shares or the price of commodities fluctuate. This includes changes in the fair value of the Brent linked and the TTF linked derivative instruments.
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•Risk of breach of certain debt covenants. Our loan agreements and lease financing arrangements require us to maintain specific financial levels and ratios, including minimum amounts of available cash, minimum ratios of current assets to current liabilities (excluding current portion of long-term debt), minimum levels of stockholders’ equity and maximum loan amounts to value. If c ertain covenants are breached, we may be required to make further principal repayments ahead of our loan maturity which would reduce our available cash.
•Our vessels' net book value may be impaired. Our vessels are reviewed for impairment whenever events or changes in circumstances, such as a sale of one or more of our vessels, indicate that the carrying amount may not be recoverable. In assessing the recoverability of our long-lived assets' carrying amounts, we make assumptions regarding estimated undiscounted future cash flows, such as the vessels' economic useful life and estimates in respect of residual or scrap value. If the market value of our vessels declines, we may be required to record an impairment charge in our financial statements, which could adversely affect our results of operations.
Please see the section of this Annual Report entitled “Item 3. Key Information - D. Risk Factors” for a discussion of certain risks inherent in our business.
Important Financial and Operational Terms and Concepts
We use a variety of financial and operational terms and concepts when analyzing our performance. These include the following:
Liquefaction services revenue. Liquefaction services revenue is generated from the LTA entered into with our customer in relation to the FLNG Hilli. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. We recognize revenue when obligations under the terms of the LTA and its subsequent addendum are satisfied. We have applied the practical expedient to recognize liquefaction services revenue in proportion to the amount we have the right to invoice.
Operating revenues (including revenue from collaborative arrangement). Total operating revenues primarily refers to time and voyage charter revenues. We recognize revenues from time and voyage charters over the term of the charter as the applicable vessel operates under the charter. We do not recognize revenue during days when the vessel is off-hire, unless the charter agreement makes a specific exception. Operating revenues includes revenues from vessels engaged in collaborative arrangements, in the Cool Pool. Specifically, for the Cool Pool, pool earnings (gross earnings of the pool less costs and overheads of the Cool Pool and fees to the Pool Manager) are aggregated and then allocated to the pool participants in accordance with the number of days each of their respective vessels are in the pool during results sharing period.
Voyage, charterhire expenses and commission expenses, net (including expenses from collaborative arrangement).
Voyage expenses, which are primarily fuel costs but which also include other costs such as port charges, are paid by our charterers under our time charters. However, we may incur voyage related expenses during off-hire periods when positioning or repositioning vessels before or after the period of a time charter or before or after drydocking. While a vessel is on-hire, fuel costs are typically paid by the charterer, whereas during periods of commercial waiting time, fuel costs are paid by us. Charterhire expenses refer to the cost of chartering-in vessels to our fleet and commissions relate to brokers' commissions. Furthermore, voyage, charterhire expenses and commission expenses, net includes related net revenue or expenses attributable to the other participants engaged in the collaborative arrangements and pooling arrangements.
Realized and unrealized gain/(loss) on oil and gas derivative instruments. Realized and unrealized gain/(loss) on the oil derivative instrument is the fair value of the oil derivative 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 Hilli's LTA. Realized and unrealized gain on the gas derivative instrument is the fair value of the gas derivative determined using the estimated discounted cash flows of the additional payments due to us as a result of forecast natural gas prices and forecast Euro/USD exchange rates. Significant inputs used in the valuation of the oil and gas derivative instruments include 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. The changes in fair value of our oil and gas derivative instruments are recognized in each period within “Realized and unrealized gain/(loss) on oil and gas derivative instruments” as part of the consolidated statement of operations.
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Adjusted EBITDA. Adjusted EBITDA is calculated by taking net income before net income/(loss) from discontinued operations, tax, interest, equity in net (losses)/income/(losses) from equity method investments, unrealized mark-to-market movements on the oil and gas derivative instruments, other non-operating income/(expenses), impairment of long-term assets and depreciation and amortization. Adjusted EBITDA is a financial measure used by management and investors to assess our total financial and operating performance. Management believes that Adjusted EBITDA assists management and investors by increasing the comparability of our total performance from period to period against the performance of other companies.
Interest expense and interest income. Interest expense depends on our and our consolidated lessor VIE entities' overall level of borrowings and all-in borrowing costs, including the amortization of deferred financing costs associated with such borrowings. Given we are deemed to be the primary beneficiary of our lessor VIEs, we have consolidated the VIEs net results into our consolidated results. Although consolidated into our results, we have no control over the funding arrangements negotiated by these lessor VIEs which includes the interest rates to be applied.
Income/(losses) from equity method investments. This includes our share of the income/(losses) from our equity method investments. Affiliates are entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but do not exercise control or have the power to control the financial and operational policies. These are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the participating rights of non-controlling interests. We record our equity method investment at cost and adjust the carrying amount for our share of the income/(losses) from our equity method investment subsequent to the date of the investment and report the recognized earnings or losses in the statement of income. The excess, if any, of the purchase price over book value of our equity method investment, or basis difference, is included in the consolidated balance sheets as “Equity method investments” amortized through the consolidated statements of operations.
Time charter equivalent (“TCE”). TCE is calculated by taking total operating revenue less liquefaction services revenue, vessel and other management fees and voyage and commission expenses, net divided by calendar days less scheduled off-hire days. It is the typical shipping industry performance measure used primarily to compare period-to-period changes in the shipping fleet's net revenue performance despite changes in the mix of charter types (i.e. spot charters, time charters and bareboat charters) under which the vessel may be employed between the periods. Management believes that TCE assists management in making decisions regarding the deployment and utilization of its shipping fleet and in evaluating financial performance.
Calendar days less offhire days. The calendar days less offhire days for our fleet is the total number of days in a given period that our vessels were in our possession less the total number of days off-hire. We define days off-hire as days lost to, among other things, operational deficiencies, drydocking for repairs, maintenance or inspection, scheduled lay-up, vessel conversions, equipment breakdowns, special surveys and vessel upgrades, delays due to accidents, crewing strikes, certain vessel detentions or similar problems, or our failure to maintain the vessel in compliance with its specifications and contractual standards or to provide the required crew, or periods of commercial waiting time during which we do not earn charter revenue.
Inflation and Cost Increases
Although inflation has had a moderate impact on operating expenses, interest costs, drydocking expenses and overheads, we do not expect inflation to have a significant impact on direct costs in the current and foreseeable economic environment other than potentially in relation to insurance costs and crew costs. LNG transportation is a business that requires specialist skills that take some time to acquire and the number of vessels is increasing. Therefore, there has been an increased demand for qualified crews, which has and will continue to the same extent to put inflationary pressure on crew costs. Only vessels on full cost pass-through charters would be fully protected from crew cost increases.
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A. Operating Results
Year ended December 31, 2021 compared with the year ended December 31, 2020
On April 15, 2021, we completed the GMLP Merger and the Hygo Merger. Prior to the GMLP Merger and Hygo Merger, we operated in four reportable segments, “Vessel and other operations, “FLNG,” “Power” and “Corporate and other.” The disposal of our interest in Hygo signaled our exit from Power operations and we ceased to consider the Power operations as a reportable segment (as defined under United States Generally Accepted Accounting Principles (“U.S. GAAP”)) with effect from the first quarter of 2021. Consequently, management has therefore concluded that we provide and operate three distinct reportable segments: “Shipping”, “FLNG” and “Corporate and other”. See note 6 “Segment Information” and note 14 “Discontinued Operations” of the audited consolidated financial statements included herein for additional information on our segments and the GMLP Merger and the Hygo Merger, respectively.
Reconciliations of the 2021 and 2020 consolidated net income/(loss) to Adjusted EBITDA are as follows:

| December 31, |  |
(in thousands of $) | 2021 | 2020 | Change | % Change
Net income/(loss) | 560,615 |  | (167,930) |  | 728,545 |  | (434) | %
Income taxes | 1,740 |  | 981 |  | 759 |  | 77 | %
Income/(loss) before income taxes | 562,355 |  | (166,949) |  | 729,304 |  | (437) | %
Depreciation and amortization | 105,952 |  | 107,923 |  | (1,971) |  | (2) | %
Unrealized (gain)/loss on oil and gas derivative instruments | (179,891) |  | 45,100 |  | (224,991) |  | (499) | %
Other non-operating losses/(income), net | 361,928 |  | (5,682) |  | 367,610 |  | (6470) | %
Interest income | (139) |  | (1,572) |  | 1,433 |  | (91) | %
Interest expense | 55,163 |  | 69,354 |  | (14,191) |  | (20) | %
(Gains)/losses on derivative instruments | (24,348) |  | 52,423 |  | (76,771) |  | (146) | %
Other financial items, net | 759 |  | 1,552 |  | (793) |  | (51) | %
Income/(losses) from equity method investments | (1,080) |  | 538 |  | (1,618) |  | (301) | %
Net (income)/loss from discontinued operations | (568,049) |  | 175,989 |  | (744,038) |  | (423) | %
Adjusted EBITDA | 312,650 |  | 278,676 |  | 33,974 |  | 12 | %

Discussed below are our financial statement line items of our consolidated results of operations for the years ended December 31, 2021 and 2020 that are not covered by the segmental analysis presented later in this section:
Depreciation and amortization: Depreciation and amortization decreased by $2.0 million to $106 million for the year ended December 31, 2021 compared to $108 million for the same period in 2020, principally due to:
•$0.2 million decrease in LNG Croatia's (formerly the Golar Viking) depreciation which relates to depreciation prior to her entry into the shipyard for conversion to a FSRU. There was no comparable charge in 2021 following her disposal in December 2020;
•$0.5 million decrease in the Golar Tundra's depreciation run-rate in 2021 given lower drydocking cost capitalized following her drydock in 2020; and
•decrease in depreciation for the year ended December 31, 2021, compared to 2020, as certain components of the vessels' costs with shorter useful economic lives, were fully depreciated in 2020.
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Unrealized (gain)/loss on the oil and gas derivative instruments: The unrealized (gain)/loss on oil and gas derivative instruments increased by $225.0 million to a gain of $179.9 million for the year ended December 31, 2021, compared to a loss of $45.1 million in 2020, principally due to:
•Unrealized (gain)/loss on Hilli oil derivative instrument: Relates to the mark-to-market movement on the fair value of the Hilli oil derivative instrument which is determined using the estimated discounted cash flows of the additional payments due to us as a result of Brent oil prices moving above a contractual oil price floor over the remaining term of the LTA. Unrealized (gain)/loss on Hilli oil derivative instrument increased by $172.0 million to a gain of $126.9 million for the year ended December 31, 2021, compared to a loss of $45.1 million for the same period in 2020, due to improvements in the future Brent oil price curves over the LTA's remaining contractual term.
•Unrealized gain on Hilli gas derivative instrument: In July 2021, we signed the Hilli Extended Capacity Agreement with the Hilli Customer which resulted in the recognition of a gas derivative asset, linked to the Dutch Title Transfer Facility (“TTF”). The mark-to-market movement on the fair value of our Hilli gas derivative asset was determined using the estimated discounted future cash flows of the additional payments due to us as a result of the future TTF gas prices and forecasted EUR/USD exchange rates. The unrealized gain on the Hilli gas derivative asset resulted in a gain of $51.3 million for the year ended December 31, 2021. There was no comparable gain recognized in 2020.
•Unrealized mark-to-market adjustment for commodity swap derivatives: As of December 31, 2021, we were party to commodity swaps to manage our exposure on the 2022 Incremental Capacity on the Hilli which resulted in an unrealized gain of $1.7 million for the year ended December 31, 2021. There was no comparable gain for 2020.
Other non-operating losses/(income), net: Other non-operating losses, net, increased by $367.6 million to $361.9 million for the year ended December 31, 2021 compared to $5.7 million income for the same period in 2020, principally due to:
•$295.8 million cumulative unrealized mark-to-market loss on our NFE shares which we received as consideration for the Hygo Merger. There was no comparable loss in 2020;
•$71.7 million contingent liability recognized in relation to the expected settlement of the UK tax lease inquiry with HMRC (note 29). There was no comparable contingent liability in 2020;
•partially offset by $5.6 million of dividend receipts from NFE; and
•the $5.7 million gain on disposal in 2020 relating to the gain on disposal of the converted FSRU vessel LNG Croatia to LNG Hrvatska (note 18). There was no comparable gain in 2021.
Interest income: Interest income decreased by $1.4 million to $0.1 million for the year ended December 31, 2021 compared to $1.6 million for the same period in 2020. The decrease was primarily due to a decrease in the returns on our fixed deposits that had been made during the year ended 2021, and a decrease in the income derived from the lending capital of our lessor VIEs, which we are required to consolidate under U.S. GAAP.
Interest expense: Interest expense decreased by $14.2 million to $55.2 million for the year ended December 31, 2021 compared to $69.4 million for the same period in 2020 due to:
•$14.4 million decrease in interest expense arising on the loan facilities of our consolidated lessor VIEs following scheduled capital repayments;
•$8.5 million decrease in interest expense relating to the refinancing of the Golar Bear facility with AVIC International Leasing Company Limited (“AVIC”) and the repayments in 2020 of the Golar Viking facility, the Margin Loan facility and the Term Facility (see note 21 “Debt” of our consolidated financial statements included herein for more information);
•$1.7 million decrease in amortization of deferred financing costs following repayments of the Golar Viking facility and the Margin Loan facility in 2020, and the amendments of our four vessels' sale and leaseback debts with ICBC Finance Leasing Co. Ltd (“ICBCL”) in 2021; and
•$1.6 million decrease in interest expense on the Golar Arctic and the Golar Frost facilities due to a reduction in LIBOR.
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This decrease in interest expense was partially offset by:
•$8.2 million increase in interest expense relating to the Norwegian Bonds and the Revolving Credit Facility (“RCF”) entered in October 2021 and December 2020, respectively; and
•$4.0 million decrease in capitalized interest on borrowing costs in relation to our qualifying investments in Hygo (subsequently disposed of) and Avenir. Hygo's Sergipe Power Plant commenced operations in late March 2020, and Avenir's first vessel was delivered in October 2020, resulting in the cessation of capitalizing interest.
Gains/(losses) on derivative instruments: Gains/(losses) on derivative instruments increased by $76.8 million to a gain of $24.3 million for the year ended December 31, 2021 compared to a loss of $52.4 million for the same period in 2020. The change is primarily due to:
•Mark-to-market adjustment for interest rate swap derivatives: As of December 31, 2021, we have an interest rate swap portfolio with a notional value of $505.0 million (2020: $597.5 million), none of which are designated as hedges for accounting purposes. Net unrealized gains on the interest rate swaps increased to a gain of $27.0 million for the year ended December 31, 2021 compared to an unrealized loss of $38.6 million for the same period in 2020. The unrealized gains were due to the increase in the long-term swap rates, partially offset by a decrease in the notional value of our swap portfolio and fair value adjustments reflecting our creditworthiness and that of our counterparties for the year ended December 31, 2021. Realized losses on our interest rate swaps decreased to a loss of $2.9 million for the year ended December 31, 2021, compared to a loss of $6.2 million for the same period in 2020, due to a reduction in LIBOR for the year ended December 31, 2021.
•Mark-to-market adjustment for equity derivative: In December 2014, we established a three-month facility for a Stock Indexed Total Return Swap Program (“Total Return Swap”) or Equity Swap Line with DNB Bank ASA in connection with a share buyback scheme. In February 2020, we repurchased the remaining 1.5 million of our shares and 0.1 million of Golar Partners' units underlying the equity swap which terminated the Total Return Swap. The equity swap derivatives mark-to-market adjustment resulted in a net loss of $5.1 million recognized in the year ended December 31, 2020. There was no comparable loss recognized in the comparable period in 2021.
Other financial items, net: Loss on other financial items, net decreased by $0.8 million to a loss of $0.8 million for the year ended December 31, 2021, compared to loss of $1.6 million for the same period in 2020 due to favorable foreign exchange movement of $2.8 million, partially offset by a decrease in the amortization of debt guarantees of $1.5 million following the disposal of our interest in Hygo.
Income/(losses) from equity method investment: Income/(losses) from equity method investments represents our share of earnings/(losses) from our equity accounted investments in Egyptian Company for Gas Services S.A.E (“ECGS”) and Avenir. The increase of $1.6 million compared to 2020 was largely due to the net income from Avenir.
Net income/(loss) from discontinued operations:

| December 31, |  |
(in thousands of $) | 2021 | 2020 | Change | % Change
Share of net earnings/(losses) of Golar Partners | 8,116 |  | (136,832) |  | 144,948 |  | (106) | %
Share of net losses of Hygo | (15,008) |  | (39,157) |  | 24,149 |  | (62) | %
Gain on disposal of equity method investments | 574,941 |  | — |  | 574,941 |  | 100 | %
Net income/(loss) from discontinued operations | 568,049 |  | (175,989) |  | 744,038 |  | (423) | %

On April 15, 2021, we completed the disposals of our interests in Golar Partners and Hygo to NFE. The net income from discontinued operations for the year ended December 31, 2021, consists of our share of earnings/(losses) from discontinued operations until April 15, 2021 and the resultant gain on disposal of our equity method investments of $574.9 million, which represents the excess consideration over the book value of our equity accounted investments disposed of.
As of December 31, 2020, we held a 32.2% ownership interest in Golar Partners (including our 2% general partner interest) and 100% of the incentive distribution rights (“IDRs”). We recognized an impairment charge of $135.9 million due to the duration and extent of the suppressed unit price of Golar Partners and we concluded that the difference between the carrying value and the fair value of our equity accounted investment was no longer temporary.
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As of December 31, 2020, we held a 50.0% ownership interest in Hygo. Our share in net losses of Hygo principally relates to trading activities of the Golar Celsius and the Golar Penguin operating as LNG carriers and the performance of the Sergipe Power Plant, including the Golar Nanook operating as a FSRU, regasifying LNG for the Sergipe Power Plant. The decrease in our share of net losses in Hygo was mainly driven by our share of the one-off non-cash loss on the deemed disposal of the Golar Nanook following the commencement of her 25-year sales type lease with Centrais Eléctricas de Sergipe S.A. (“CELSE”) in 2020.
The following details the operating results and Adjusted EBITDA for our reportable segments for the years ended December 31, 2021 and 2020.

| December 31, 2021 | December 31, 2020
(in thousands of $) | Shipping | FLNG | Corporate and other | Total | Shipping | FLNG | Corporate and other | Total
Total operating revenues | 202,968 |  | 221,020 |  | 27,777 |  | 451,765 |  | 191,881 |  | 226,061 |  | 20,695 |  | 438,637 |
Vessel operating expenses | (57,010) |  | (51,196) |  | (12,119) |  | (120,325) |  | (57,326) |  | (52,104) |  | 504 |  | (108,926) |
Voyage, charterhire and commission expenses, net | (10,340) |  | (600) |  | 166 |  | (10,774) |  | (12,634) |  | — |  | — |  | (12,634) |
Administrative expenses | (644) |  | (397) |  | (33,980) |  | (35,021) |  | (2,211) |  | (1,672) |  | (31,428) |  | (35,311) |
Project development expenses | — |  | (2,974) |  | 187 |  | (2,787) |  | (112) |  | (2,793) |  | (5,986) |  | (8,891) |
Realized gain on oil derivative instrument | — |  | 24,772 |  | — |  | 24,772 |  | — |  | 2,539 |  | — |  | 2,539 |
Other operating income | 5,020 |  | — |  | — |  | 5,020 |  | 3,262 |  | — |  | — |  | 3,262 |
Adjusted EBITDA | 139,994 |  | 190,625 |  | (17,969) |  | 312,650 |  | 122,860 |  | 172,031 |  | (16,215) |  | 278,676 |

Shipping segment

| December 31, |  |
(in thousands of $, except average daily TCE) | 2021 | 2020 | Change | % Change
Total operating revenues | 202,968 |  | 191,881 |  | 11,087 |  | 6 | %
Vessel operating expenses | (57,010) |  | (57,326) |  | 316 |  | (1) | %
Voyage, charterhire and commission expenses, net | (10,340) |  | (12,634) |  | 2,294 |  | (18) | %
Administrative expenses | (644) |  | (2,211) |  | 1,567 |  | (71) | %
Project development expenses | — |  | (112) |  | 112 |  | 100 | %
Other operating income | 5,020 |  | 3,262 |  | 1,758 |  | 54 | %
Adjusted EBITDA | 139,994 |  | 122,860 |  | 17,134 |  | 14 | %
Other Financial Data: |  |  |  |
Total operating revenues minus voyage, charterhire and commission expenses, net | 192,628 |  | 179,247 |  | 13,381 |  | 7 | %
Calendar days less scheduled off-hire days | 3,631 |  | 3,669 |  | (38) |  | (1) | %
Average daily TCE (1) (to the closest $100) | 52,900 |  | 48,900 |  | 4,000 |  | 8 | %

(1) Average daily TCE is a non-GAAP financial measure and is calculated by taking the total operating revenue minus voyage, charterhire and commission expenses, net divided by calendar days less scheduled off-hire days. See “Item 5. Important financial and operational terms and concepts”.
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Total operating revenues: Operating revenues increased by $11.1 million to $203.0 million for the year ended December 31, 2021 compared to $191.9 million in 2020. This was principally due to :
•our fleet's utilization for the year ended December 31, 2021 of 98% with 23 commercial waiting days, compared to the same period in 2020 of 86% utilization with 318 commercial waiting days and higher daily charter rates earned by our vessels;
•$17.0 million increase in revenue from the Golar Tundra due to her full utilization during 2021, compared to 120 off-hire days as a result of her scheduled drydock during the same period in 2020;
•$10.9 million increase in revenue from the Golar Ice due to less off-hire days as a result of her engine breakdowns between 2021 of 53 days and 2020 of 69 days. Further increased as a result of vessel exiting the Cool Pool and benefiting from increased daily charter hire rates in 2021, compared to 2020; and
•partially offset by $16.4 million decrease in revenue from the remaining TFDE LNG carriers not discussed above and the Golar Arctic for the year ended December 31, 2021 compared to the same period in 2020, due to lower charterhire rates.
Average daily TCE: Average daily TCE of $52,900 for the year ended December 31, 2021, is 8% higher than the same period in 2020. The increase in the daily TCE was due to higher fleet utilization and higher daily charter rates earned by our vessels for the year ended December 31, 2021, compared to the same period in 2020.
Voyage, charterhire and commission expenses, net: Voyage, charterhire and commission expenses largely relate to charterhire expenses, fuel costs associated with commercial waiting time and vessel positioning costs. While a vessel is on-hire, fuel costs are typically paid by the charterer, whereas during periods of commercial waiting time, fuel costs are paid by us. The decrease in voyage, charterhire and commission expenses of $2.3 million to $10.3 million for the year ended December 31, 2021 compared to $12.6 million for the same period in 2020, was principally due to:
•$1.5 million decrease in bunker consumption incurred in relation to the LNG Croatia prior to entering the shipyard for conversion in late January 2020;
•$1.3 million reduction in voyage expenses relating to the chartering of an external vessel, which we have subsequently sub-chartered contributing to our total operating revenue; and
•$1.1 million increase in bunker consumption in relation to the Golar Ice due to the replacement of engine in the yard for the year ended December 31, 2021.
Administrative expenses: Administrative expenses decreased by $1.6 million to $0.6 million for the year ended December 31, 2021 compared to $2.2 million for the same period in 2020, mainly due to ongoing cost reduction measures.
Other operating income: Other operating income mainly comprised of the Golar Ice's loss of hire insurance receipts of $5.0 million and $2.7 million for the year ended December 31, 2021 and 2020, respectively.
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FLNG segment

| December 31, |  |
(in thousands of $) | 2021 | 2020 | Change | % Change
Total operating revenues | 221,020 |  | 226,061 |  | (5,041) |  | (2) | %
Vessel operating expenses | (51,196) |  | (52,104) |  | 908 |  | (2) | %
Voyage, charterhire and commission expenses | (600) |  | — |  | (600) |  | 100 | %
Administrative expenses | (397) |  | (1,672) |  | 1,275 |  | (76) | %
Project development expenses | (2,974) |  | (2,793) |  | (181) |  | 6 | %
Realized gains on oil derivative instrument | 24,772 |  | 2,539 |  | 22,233 |  | 90 | %
Adjusted EBITDA | 190,625 |  | 172,031 |  | 18,594 |  | 11 | %

Total operating revenues: The Hilli maintained her 100% commercial uptime during the year, reaching her 66th successful offloading for the year ended December 31, 2021. Total operating revenues decreased by $5.0 million to $221.0 million for the year ended December 31, 2021, compared to $226.1 million for the same period in 2020, due to $4.7 million lower overproduction revenue recognized in 2021. In 2020, we entered into an addendum to the Hilli's LTA with our Customer, for us to be compensated for any production in excess of the base capacity set out in the LTA and recognized $8.0 million for the year ended December 31, 2020 for the overproduction in relation to the years 2020 and 2019.
Vessel operating expenses: Vessel operating expenses decreased by $0.9 million to $51.2 million for the year ended December 31, 2021, compared to $52.1 million for the same period in 2020, mainly due to a decrease of $2.2 million in crew costs following logistical restrictions brought about by COVID-19, partially offset by $1.6 million increase in Hilli's insurance costs and management fees.
Voyage, charterhire and commission expenses: Voyage, charterhire and commission expenses increased to $0.6 million for the year ended December 31, 2021, due to the reclassification of $0.6 million for Hilli's and Gandria's commercial management fees from administrative expenses in 2021.
Administrative expenses: Administrative expenses decreased by $1.3 million to $0.4 million for the year ended December 31, 2021, compared to $1.7 million for the same period in 2020, mainly due to the reclassifications of $0.6 million for Hilli's and Gandria's commercial management fees to voyage, charterhire and commission expenses in 2021.
Realized gain on oil derivative instrument: Realized gains on the oil derivative instrument, which is based on a three-month look-back at the average Brent crude oil prices above the base tolling fee under the Hilli's LTA, increased by $22.2 million to $24.8 million for the year ended December 31, 2021 compared to $2.5 million in 2020, due to an increase in forecasted future Brent crude oil prices.
Corporate and other segment

| December 31, |  |
(in thousands of $) | 2021 | 2020 | Change | % Change
Total operating revenues | 27,777 |  | 20,695 |  | 7,082 |  | 34 | %
Vessel operating expenses | (12,119) |  | 504 |  | (12,623) |  | 104 | %
Voyage, charterhire and commission expenses | 166 |  | — |  | 166 |  | 100 | %
Administrative expenses | (33,980) |  | (31,428) |  | (2,552) |  | 8 | %
Project development expenses | 187 |  | (5,986) |  | 6,173 |  | (103) | %
Adjusted EBITDA | (17,969) |  | (16,215) |  | (1,754) |  | 11 | %

Total operating revenues: Total operating revenues increased by $7.1 million to $27.8 million for the year ended December 31, 2021, compared to $20.7 million for the same period in 2020. This was primarily due to:
•$10.8 million increase in vessel management fees billed pursuant to the O&M Agreement with LNG Hrvatska, which commenced in January 2021; and
•partially offset by $3.3 million decrease in vessel management fees relating to lower administrative services fees charged to our former affiliates, Golar Partners and Hygo.
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Vessel operating expenses: Vessel operating expenses increased by $12.6 million to $12.1 million for the year ended December 31, 2021, compared to $0.5 million credit for the same period in 2020, primarily due to costs associated to the O&M Agreement on the LNG Croatia.
Administrative expenses: Administrative expenses increased by $2.6 million to $34.0 million for the year ended December 31, 2021 compared to $31.4 million for the same period in 2020, mainly due to:
•$4.5 million increase in corporate expenses including legal and professional fees, audit fees and employee related costs as a result of one-off redundancy costs from a corporate overhead streamlining exercise; and
•partially offset by $1.9 million decrease in share options and restricted stock units (“RSUs”) expenses due to lesser share options awards which vested in 2021 and forfeitures of RSUs as a consequence of a corporate overhead streamlining exercise.
Project development expenses: Project development expenses decreased by $6.2 million to $0.2 million credit for the year ended December 31, 2021 compared to $6.0 million for the same period in 2020, mainly due to non-recurring 2020 expenses related to strategic initiatives and corporate simplification, consisting of $5.6 million of professional, legal and consultancy costs.
Please refer to Golar LNG Limited's Annual Report on Form 20-F for the fiscal year ended December 31, 2020 filed on April 22, 2021, Item 5 Operating and financial review and prospects - A. Operating results, for the management discussion and analysis of the operating results for year 2020 compared to 2019.
B. Liquidity and Capital Resources
Liquidity and Cash Requirements
We operate in a capital intensive industry, and we have historically financed the purchase of our vessels, conversion projects and other capital expenditures through a combination of borrowings from debt transactions, leasing arrangements with financial institutions, cash generated from operations, sales of vessels and equity capital. Our liquidity requirements relate to servicing our debt, funding our conversion projects, funding investment in the development of our project portfolio, including our affiliates, funding working capital, payment of dividends and maintaining cash reserves to satisfy certain of our borrowing covenants (including cash collateral requirements in respect of certain of our derivatives and as security for the provision of letters of credit) and to offset fluctuations in operating cash flows.
Our funding and treasury activities are conducted within our established corporate policies to maximize investment returns while maintaining appropriate liquidity for our requirements. Cash and cash equivalents are held primarily in U.S. dollars with some balances held in British Pounds, Singapore Dollars, Norwegian Kroners, Euros and Central African Franc. We have made use of derivative instruments for interest rate, currency and commodity risk management purposes.
Our short-term liquidity requirements are primarily for the servicing of debt, working capital, potential investments and conversion project related commitments due within the next 12 months. We may require additional working capital for the continued operation of our vessels in the spot market, which is dependent upon vessel employment and fuel costs incurred during idle time.
As of December 31, 2021, we had cash and cash equivalents (including short-term deposits) of $418.8 million, of which $150.2 million is restricted cash. Included within restricted cash is $60.7 million in respect of the issuance of the LC by a financial institution to our project partner involved in the Hilli FLNG project, $16.0 million in relation to liability for UK tax leases, $11.3 million in respect of the O&M Agreement as part of the sale of LNG Croatia, with the balance mainly relating to the cash belonging to lessor VIEs that we are required to consolidate under U.S. GAAP. Refer to note 15 “Restricted Cash and Short-term Deposits” of our consolidated financial statements included herein for additional details.
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Since December 31, 2021, significant transactions impacting our cash flows include:
Receipts:
•$253.0 million of net proceeds from the sale of 6.2 million NFE shares in April 2022;
•$211.7 million of cash proceeds as part purchase consideration in relation to the closing of the Cool Co Vessel SPA across March and April 2022;
•$131.0 million drawdown on Revolving Credit Facility in February 2022;
•$75.0 million drawdown from the Gimi facility in February 2022 and a further $50.0 million drawdown in April 2022;
•$11.3 million proceeds from First FLNG Holdings' subscription of equity interest in Gimi MS; and
•$2.4 million dividend receipt relating to our investment in NFE.
Payments:
•$321.7 million full redemption at maturity of 2017 Convertible Bonds, in February 2022, representing outstanding notional amount and accrued interest;
•$78.9 million of additions to the assets under development.
•$63.5 million payment to HMRC in April 2022 for the final settlement of our liability in relation to past UK tax leases, of which $16.0 million was from our restricted cash;
•$7.4 million of payments in relation to our TTF margin exposure under our commodity swap arrangements;
•$25.7 million of scheduled loan principal and interest repayments;
•$6.6 million payments in relation to our share repurchase program in March 2022;
•$2.5 million payment in relation to arrangement fees for the corporate bilateral facility; and
•$1.3 million of scheduled payments in relation to settlement of our commodity swap arrangements.
Medium to Long-term Liquidity and Cash Requirements
Our medium and long-term liquidity requirements are primarily for funding future investments and our conversion projects and repayment of long-term debt balances. Sources of funding for our medium and long-term liquidity requirements include new loans, refinancing of existing financing arrangements, and public and private debt or equity offerings.
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Cash Flows
The following table summarizes our cash flows from operating, investing and financing activities for the periods indicated.

| Year ended December 31,
(in millions of $) | 2021 |  | 2020 |  | 2019
Net cash provided by continuing operating activities | 253.9 |  |  | 145.8 |  |  | 106.5 |
Net cash used in continuing investing activities | (194.3) |  |  | (111.2) |  |  | (283.5) |
Net cash provided by discontinued investing activities | 120.0 |  |  | 8.2 |  |  | 19.1 |
Net cash used in financing activities | (51.6) |  |  | (162.3) |  |  | (136.0) |
Net increase/(decrease) in cash, cash equivalents and restricted cash | 128.0 |  |  | (119.5) |  |  | (293.9) |
Cash, cash equivalents and restricted cash at beginning of year | 290.9 |  |  | 410.4 |  |  | 704.3 |
Cash, cash equivalents and restricted cash at end of year | 418.9 |  |  | 290.9 |  |  | 410.4 |

Net cash provided by continuing operating activities
Cash provided by continuing operating activities increased by $108.1 million to $253.9 million for the year ended December 31, 2021 compared to $145.8 million for the same period in 2020. The increase was primarily due to:
•higher contribution recognized from our participation in the Cool Pool due to higher utilization and charter rates from our vessels for the year ended December 31, 2021, compared to the same period in 2020;
•$9.0 million reduction of dry docking costs paid for the year ended December 31, 2021, compared to the same period in 2020, due to the timing of the scheduled dry-docks; and
•the improvement in the general timing of working capital for the year ended December 31, 2021, compared to the same period in 2020, driven by on-going cost saving measures.
Net cash used in continuing investing activities
Net cash used in continuing investing activities of $194.3 million in 2021 comprised of:
•$213.5 million of additions to asset under development relating to payments made in respect of the conversion of the Gimi inclusive of interest costs capitalized;
•$8.6 million of additional equity contribution to our investment in Avenir;
•$1.8 million revolving shareholder loan to Avenir;
•partially offset by $25.4 million of proceeds from First FLNG Holdings' subscription of 30% of additional equity interest in Gimi MS; and
•$5.0 million of dividends received in relation to our 18.6 million shares of Class A NFE common stock (“NFE Shares”).
Net cash used in continuing investing activities of $111.2 million in 2020 comprised mainly of:
•$298.3 million of additions to assets under development relating to payments made in respect of the conversion of the Gimi and the LNG Croatia;
•$10.2 million of additional equity contribution to our investment in Avenir;
•$3.9 million of payments in relation to the installation of the Golar Tundra's ballast water treatment systems;
•Partially offset by $190.1 million of proceeds from the disposal of the LNG Croatia to LNG Hrvatska; and
•$11.1 million proceeds from First FLNG Holdings' subscription of 30% of additional equity interest in Gimi MS.
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Net cash used in by discontinued investing activities
Net cash provided by discontinued investing activities of $120.0 million in 2021 is comprised of:
•$119.5 million of net proceeds from disposals of our equity accounted investments in Golar Partners and Hygo; and
•$0.5 million of dividends received from Golar Partners (subsequently disposed of).
Net cash provided by discontinued investing activities of $8.2 million in 2020 is comprised of:
•$45.0 million of receipts from Golar Partners for repayment of loans;
•$10.6 million of dividends received from Golar Partners (subsequently disposed of);
•partially offset by $45.0 million of short term-loans advanced to Golar Partners; and
•$2.4 million of additions to our investment in Hygo (subsequently disposed of).
Net cash used in financing activities
Net cash used in financing activities is principally debt refinancing, debt repayments, cash dividends partially offset by funds from new debt. Net cash used in financing activities of $51.6 million in 2021 is comprised of:
•$271.2 million scheduled debt repayments, which includes repayments made by our lessor VIE's (see note 5 “Variable Interest Entities” of our consolidated financial statements included herein);
•$102.1 million repayment in full of the sale and leaseback facility related to Golar Tundra;
•$100.0 million repayment of the Revolving Credit Facility;
•$84.0 million partial redemption of 2017 Convertible bonds;
•$33.1 million dividend payment in relation to Hilli LLC;
•$24.5 million payment in relation to the share repurchase program; and
•$17.0 million financing costs paid predominately in relation to the Gimi, Revolving Credit and Golar Tundra facilities and the unsecured Norwegian Bonds.
This was partially offset by debt proceeds of:
•$299.0 million following completion of the unsecured Norwegian Bonds in October 2021;
•$158.0 million on the new Golar Tundra debt facility;
•$110.0 million collectively representing the fifth and sixth draw downs under the $700 million Gimi facility; and
•$13.3 million in borrowings made by our lessor VIE's (see note 5 “Variable Interest Entities” of our consolidated financial statements included herein).
Net cash used in financing activities of $162.3 million in 2020 comprised mainly of:
•$442.7 million scheduled debt repayments, which includes repayments made by our lessor VIE's (see note 5 “Variable Interest Entities” of our consolidated financial statements included herein);
•$250.0 million repayment of the Margin Loan and the Term facility;
•$124.7 million repayment of the sale and leaseback facility related to LNG Croatia, including $0.5 million of financing cost upon the disposal of the LNG Croatia;
•$117.1 million payment following the refinancing of the Golar Bear and Golar Viking facilities with sale and leaseback arrangements;
•$26.1 million dividend payment in relation to Hilli LLC;
•$16.7 million to repurchase the shares and units underlying our equity swap in February 2020; and
•$14.6 million financing costs paid predominantly in relation to the Golar Viking and Gimi facilities.
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This was partially offset by proceeds of:
•$459.7 million in relation to borrowings made by our lessor VIE's (see note 5 “Variable Interest Entities” of our consolidated financial statements included herein);
•$170.0 million being the third and fourth draw down under the $700 million Gimi facility;
•$100.0 million on the Revolving Credit Facility; and
•$99.8 million of net proceeds from the issuance of equity.
Please refer to Golar LNG Limited's Annual Report on Form 20-F for the fiscal year ended December 31, 2020 filed on April 22, 2021, Item 5 Operating and financial review and prospects - B. Liquidity and Capital Resources - Cash flows, for the management discussion and analysis of the operating results for year 2020 compared to 2019.
Borrowing Activities
As of December 31, 2021, we were in compliance with all our covenants under our various loan agreements. See note 21 “Debt” and note 30 “Subsequent Events” in our consolidated financial statements included herein for additional information.
Derivatives
We use financial instruments to reduce the risk associated with fluctuations in interest rates, foreign currency exchange rates and commodity prices. See note 27 “Financial Instruments” in our consolidated financial statements included herein for additional information.
Capital Commitments
Our conversion commitments relate to Gimi's conversion to a FLNG, further described in note 18, “Asset Under Development”, and note 29, “Commitments and Contingencies”, of our consolidated financial statements included herein for additional information.
Contractual Obligations
The following table sets forth our contractual obligations for the periods indicated as at December 31, 2021:

(in millions of $) | Total Obligation |  | Due in 2022 |  | Due in 2023 – 2024 |  | Due in 2025 – 2026 |  | Due Thereafter
Golar long-term and short-term debt (note 21) (1) | 1,266.9 |  |  | 343.8 |  |  | 129.2 |  |  | 544.3 |  |  | 249.6 |
VIE long-term and short-term debt (note 21) (1) | 1,175.0 |  |  | 708.8 |  |  | 241.4 |  |  | 189.3 |  |  | 35.6 |
Interest commitments on long-term debt and other interest rate swaps (2) | 305.1 |  |  | 62.2 |  |  | 114.0 |  |  | 81.6 |  |  | 47.3 |
FLNG conversion (note 18) | 715.5 |  |  | 378.2 |  |  | 337.3 |  |  | — |  |  | — |
Operating lease obligations (note 13) | 11.7 |  |  | 3.8 |  |  | 3.6 |  |  | 4.3 |  |  | — |
Short-term shareholder loan (3) | 3.5 |  |  | 3.5 |  |  | — |  |  | — |  |  | — |
Total | 3,477.8 |  |  | 1,500.3 |  |  | 825.5 |  |  | 819.5 |  |  | 332.5 |

(1)The obligations under long-term and short-term debt above are presented gross of deferred finance charges and exclude interest.
(2)Our interest commitment on our long-term debt is calculated based on assumed LIBOR rates of between 0.12% to 1.93% and takes into account our various margin rates and interest rate swaps associated with each financing arrangement.
(3)As at December 31, 2021, we had a commitment of $3.5 million in relation to a one year shareholder loan to Avenir. See note 28 “Related Party Transactions” of our consolidated financial statements included herein.
Please see note 30 “Subsequent events” of our consolidated financial statements included herein for more information.
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C. Research and Development, Patents and Licenses
Not applicable.
D. Trend Information
Please see the sections of this Item 5 entitled “Significant Developments in Early 2021,” “Factors Affecting Our results of Operations and Future Results” and “A. Operating Results” and “Item 4. Information on the Company B. Business Overview.”
The ongoing Ukraine-Russia war has resulted in the implementation of numerous actions by governments and governmental agencies around the world in an attempt to de-escalate tensions between Ukraine and Russia. The war has resulted in an extreme volatility in the global financial markets, and as a result the global demand for oil, natural gas, LNG and LNG supply has increased significantly. The scale and duration of the Ukraine-Russia war remains uncertain and could materially impact our earnings and cash flow for the 2022 fiscal year. See “Item 3.D - Risk Factors” included herein for additional information.
E. Critical Accounting Policies and Estimates
The preparation of our financial statements in accordance with U.S. GAAP requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The following is a discussion of the accounting policies applied by us that we consider to involve a higher degree of judgment. See also note 2 “Accounting Policies” of our consolidated financial statements included herein.
Revenue and related expense recognition
Revenues include minimum lease payments under time charters, fees for repositioning vessels and gross pool revenues. Revenues generated from time charters, which we classify as operating leases, are recorded over the term of the charter as service is provided. However, we do not recognize revenue if a charter has not been contractually committed to by a customer and ourselves, even if the vessel has discharged its cargo and is sailing to the anticipated load port on its next voyage.
Repositioning fees (which are included in time charter revenue) 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. Where a vessel undertakes multiple single voyage time charters, revenue is recognized, including the repositioning fee if fixed and determinable, on a discharge-to-discharge basis. Under this basis, revenue is recognized evenly over the period from departure of the vessel from its last discharge port to departure from the next discharge port. For arrangements where operating costs are borne by the charterer on a pass through basis, the pass through of operating costs is reflected in revenue and expenses.
Liquefaction services revenue is generated from a LTA entered into with our customer. Our provision of liquefaction services capacity includes the receipt of the customer’s gas, treatment and temporary storage on board our FLNG, and delivery of LNG to waiting carriers. The liquefaction services capacity provided to our customer is considered a single performance obligation recognized evenly over time as our services are rendered. We consider our services a series of distinct services that are substantially the same and have the same pattern of transfer to our customer. 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.
Revenues generated from management fees are recorded ratably over the term of the contract as services are provided.
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Vessels and impairment
Description: We review vessels and equipment for impairment whenever events or circumstances indicate the carrying value of the vessel may not be fully recoverable. Management performs an annual impairment assessment and when such events or circumstances are present, we assess recoverability by comparing the vessel's projected undiscounted net cash flows to its carrying value. If the total projected undiscounted net cash flows are lower than the vessel’s carrying value, we recognize an impairment loss measured as the excess of the carrying amount over the fair value of the vessel. As of December 31, 2021, for nine of our vessels (see note 19 “Vessels and Equipment, net” of our consolidated financial statements included herein), the carrying value was higher than their estimated market values (based on third party average ship broker valuations). As a result, we concluded that an impairment trigger existed and performed a recoverability assessment for each of these vessels. However, no impairment loss was recognized as, for each of these vessels, the projected undiscounted net cash flows were significantly higher than the carrying value.
Judgments and estimates: The cash flows on which our assessment of recoverability is based is highly dependent upon our forecasts, which are highly subjective and, although we believe the underlying assumptions supporting this assessment are reasonable and appropriate at the time they were made, it is therefore reasonably possible that a further decline in the economic environment could adversely impact our business prospects in the next year. This could represent a triggering event for a further impairment assessment.
Accordingly, the principal assumptions we have used in our recoverability assessment (i.e. projected undiscounted net cash flows basis) included, among others, charter rates, vessel operating expenses, drydocking requirements and residual value. These assumptions are based on historical trends but adjusted for future expectations. Specifically, forecasted charter rates are based on information regarding current spot market charter rate (based on a third party information), option renewal rate with the existing counterparty or existing long-term charter rate, in addition to industry analyst and broker reports. Estimated outflows for operating expenses and drydockings are based on historical costs.
Effect if actual results differ from assumptions: Although we believe the underlying assumptions supporting our impairment assessment are reasonable, if charter rate trends and the length of the current market downturn vary significantly from our forecasts, management may be required to perform step two of the impairment analysis that could expose us to material impairment charges in the future. Our estimates of vessel market values may not be indicative of the current or future market value of our vessels or prices that we could achieve if we were to sell them and a material loss might be recognized upon the sale of our vessels.
Vessel market values
Description: Under “Vessels and impairment”, we discuss our policy for assessing impairment of the carrying values of our vessels. During the past few years, the market values of certain vessels in the worldwide fleet have experienced particular volatility, with substantial declines in many vessel classes. There is a future risk that the market value of certain of our vessels could decline below those vessels' carrying value, even though we would not recognize an impairment for those vessels due to our belief that projected undiscounted net cash flows expected to be earned by such vessels over their operating lives would exceed such vessels' carrying amounts.
Judgments and estimates: Our estimates of market value assume that our vessels are all in good and seaworthy condition without need for repair and, if inspected, would be certified in class without notations of any kind. Our estimates for our LNG carriers, FSRU and FLNG are based on approximate vessel market values that have been received from third party ship brokers, which are commonly used and accepted by our lenders for determining compliance with the relevant covenants in our credit facilities. Vessel values can be highly volatile, such that our estimates may not be indicative of the current or future market value of our vessels or prices that we could achieve if we were to sell. In addition, the determination of estimated market values may involve considerable judgment given the illiquidity of the second hand market for these types of vessels.
Effect if actual results differ from assumptions: As of December 31, 2021, while we intend to hold and operate our vessels, were we to hold them for sale, we have determined the fair market value of our vessels, with the exception of the nine vessels, were greater than their carrying value. With respect to these nine vessels, the carrying value of these vessels exceeded their aggregate market value. However, as discussed above, for each of these vessels, the carrying value was less than its projected undiscounted net cash flows, consequently, no impairment loss was recognized. See Item 18. Financial Statements: note 30 “Subsequent Events” for discussion on the subsequent disposals of eight vessels from our fleet.
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Recently Issued Accounting Standards
See Item 18. Financial Statements: note 3 “Recently Issued Accounting Standards”.
ITEM 6. DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES
A. Directors and Senior Management
Directors
The following provides information about each of our directors as of the date of this annual report.

Name |  | Age |  | Position
Tor Olav Trøim |  | 59 |  | Chairman of our Board of Directors and Director
Daniel Rabun |  | 67 |  | Director, Audit Committee member, Compensation Committee member and Nomination Committee member
Thorleif Egeli |  | 58 |  | Director
Carl Steen |  | 71 |  | Director, Audit Committee member, Compensation Committee member and Nomination Committee member
Niels Stolt-Nielsen |  | 57 |  | Director and Compensation Committee member
Lori Wheeler Naess |  | 51 |  | Director and Audit Committee Chairperson
Georgina Sousa |  | 72 |  | Director

Tor Olav Trøim has served as a director of the Company since September 2011 and appointed as the Chairman of the Board in September 2017. Mr. Trøim is founder and sole shareholder of Magni Partners. He is the senior partner (and an employee) of Magni Partners’ subsidiary, Magni Partners Limited, in the U.K. Mr. Trøim is a beneficiary of the Drew Trust, and the sole shareholder of Drew Holdings Limited. Mr. Trøim has 30 years of experience in energy related industries in various positions. Before founding Magni Partners in 2014, Mr. Trøim was a Director of Seatankers Management Co. Ltd. from 1995 until September 2014. He was Chief Executive Officer of DNO AS from 1992 to 1995 and an Equity Portfolio Manager with Storebrand ASA from 1987 to 1990. Mr. Trøim graduated with an MSc degree in naval architecture from the University of Trondheim, Norway in 1985. Mr. Trøim is a Norwegian citizen and a resident of the United Kingdom. Other directorships and management positions include, Magni Partners (Bermuda) Limited (Founding Partner), Borr Drilling Limited (Director), Golar LNG Partners LP (Chairman) (until April 15, 2021), Stolt-Nielsen SA. (Director), Magni Sports AS (Director) and Valerenga Football AS (Director).
Daniel Rabun has served as a director since February 2015 and was appointed Chairman in September 2015. Mr. Rabun resigned as Chairman in September 2017 and was appointed a non-executive director on that date. He also serves on our Audit Committee, Compensation Committee and Nomination Committee. He joined Ensco plc in March 2006 as President and as a member of the Board of Directors. Mr. Rabun was appointed to serve as Ensco's Chief Executive Officer from January 1, 2007 and elected Chairman of the Board of Directors in May 2007. Mr. Rabun retired from Ensco as President and Chief Executive Officer in May 2014 and as Chairman in May 2015. Prior to joining Ensco, Mr. Rabun was a partner at the international law firm of Baker & McKenzie LLP where he had practiced law since 1986. In May 2015, Mr. Rabun became a non-executive director and currently serves a member of the Audit Committee and the Governance and Nominations Committee of APA Corporation (formerly Apache Corp.). In May 2018, Mr. Rabun became Chairman of the Board and a member of the Compensation Committee and Governance and Nominations Committee of ChampionX Corporation. He has been a U.S. Certified Public Accountant since 1976 and a member of the Texas Bar since 1983. Mr. Rabun holds a Bachelor of Business Administration Degree in Accounting from the University of Houston and a Juris Doctorate Degree from Southern Methodist University.
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Thorleif Ege li was appointed to the Board in September 2018, Mr. Egeli was, until May 2018, Vice President of Schlumberger Production Management – North America managing the non-operating E&P assets for Schlumberger in the US, Canada and Argentina. Prior to this he held a number of senior positions within Schlumberger having begun his career with Schlumberger in 1990 as a field engineer. Between October 2009 and April 2013 Mr. Egeli held a number of positions within Archer including President Latin America, Corporate Marketing and Chief Operating Officer; before re-joining Schlumberger in 2013. Appointed in June 2018, Mr. Egeli also serves on the Board of Directors of Stimline, an international well intervention and completion company headquartered in Kristiansand Norway. Mr. Egeli also serves on the Board of Directors at the Norwegian American Chamber of Commerce, South West Chapter in Houston, Texas. Other current directorships and management positions also include Golar LNG Limited (Director) and its various subsidiaries in Bermuda (Director) and the Marshall Islands (Director and Vice President). Mr. Egeli holds a Master of Science (MSc) in Mechanical Engineering and an MBA from Rotterdam School of Management, Holland.
Carl Steen has served as a director since January 2015 and currently serves on our Audit Committee, Compensation Committee and Nomination Committee. From August 2012 until the closing of the GMLP Merger, Mr. Steen has also served as a director of Golar Partners. Mr. Steen graduated in 1975 from ETH Zurich Switzerland with a M.Sc in Industrial and Management Engineering. After working for a number of high profile companies, Mr. Steen joined Nordea Bank from January 2001 to February 2011 as head of the bank’s Shipping, Oil Services & International Division. Mr. Steen holds directorship positions in various Norwegian and international companies including Euronav NV, Wilhelmsen Holding ASA and Belships ASA.
Niels Stolt-Nielsen joined the Board in September 2015 and serves on our Compensation Committee. He is also CEO, Director and a shareholder of Stolt-Nielsen Limited, which includes world-leading businesses in global bulk-liquid and chemical logistics, an innovative business in land-based aquaculture and a number of LNG joint ventures and investments. Mr. Stolt-Nielsen is the Chairman of Avenir LNG. He brings with him extensive shipping, logistical and strategic leadership experience.
Lori Wheeler Naess was appointed as a director and Audit Committee Chairperson in February 2016. Ms. Naess also serves on the Board and Audit Committee of Opera Limited, a U.S.-listed company. Ms. Naess was a director at PricewaterhouseCoopers in Oslo and was a Project Leader for the Capital Markets Group. Between 2010 and 2012, she was a Senior Advisor for the Financial Supervisory Authority in Norway and prior to this she was also with PricewaterhouseCoopers in roles in the U.S., Norway and Germany. Ms. Naess is a U.S. Certified Public Accountant (inactive).
Georgina Sousa was appointed as a director in September 2019. She also served as secretary from May 2019 until March 2022. She currently serves as a director of Himalaya Shipping Ltd., a company listed on the Oslo Stock Exchange. Ms. Sousa was employed by Golar Management (Bermuda) Limited (GMBL) as Managing Director from January 2019 until her retirement on March 2022. She previously served as a director and secretary of Borr Drilling Limited, a company listed on both the NYSE and the OSE and 2020 Bulkers Ltd., listed on the OSE from February 2019 to February 2022. Prior to joining GMBL, Ms. Sousa was employed by Frontline Ltd. as Head of Corporate Administration from February 2007 until December 2018. She previously served as a director of Frontline Ltd. from April 2013 until December 2018, North Atlantic Drilling Ltd. from September 2013 until June 2018, Sevan Drilling Limited from August 2016 until June 2018, Northern Drilling Ltd. from March 2017 until December 2018 and Flex LNG LTD. from June 2017 until December 2018. Ms. Sousa also served as a director of Seadrill Limited from November 2015 until July 2018. Ms. Sousa served as secretary for all the above-mentioned companies at various times during the period between 2005 and 2018. Until January 2007, Ms. Sousa was Vice-President Corporate Services of Consolidated Services Limited, a Bermuda Management Company, having joined the firm in 1993 as Manager of Corporate Administration. From 1976 to 1982 Ms. Sousa was employed by the Bermuda law firm of Appleby, Spurling & Kempe as secretary and from 1982 to 1993, she was employed by the Bermuda law firm of Cox & Wilkinson as senior company secretary. Ms. Sousa is a UK citizen and resides in Bermuda.
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Board diversity
The table below provides certain information regarding the diversity of our board of directors as of the date of this annual report.

Board Diversity Matrix
Country of Principal Executive Office: | Bermuda
Foreign Private Issuer | Yes
Disclosure Prohibited under Home Country Law | No
Total Number of Directors | 7
| Female | Male | Non-Binary | Did Not Disclose Gender
Part I: Gender Identity |  |  |  |
Directors | 2 | 5 | — | —
Part II: Demographic Background |  |  |  |
Underrepresented Individual in Home Country Jurisdiction | —

Executive Officers
The following provides information about each of our executive officers as of the date of this annual report:

Name |  | Age |  | Position
Iain Ross |  | 60 |  | Chief Executive Officer – Golar Management (resigned April 12, 2021)
Karl Fredrik Staubo |  | 35 |  | Chief Executive Officer – Golar Management (from May 13, 2021)
Eduardo Maranhão |  | 38 |  | Chief Financial Officer – Golar Management (from May 13, 2021)
Øistein Dahl |  | 61 |  | Chief Operating Officer – Golar Management Norway (resigned April 1, 2022)
Ragnar Nes |  | 54 |  | Chief Operating Officer – Golar Management Norway (from April 1, 2022)
Olve Skjeggedal |  | 47 |  | Chief Technical Officer – Golar Management Norway

Iain Ross has served as Chief Executive Officer (“CEO”) from September 21, 2017. On April 12, 2021, Mr. Iain Ross announced his resignation as our CEO.
Karl Fredrik Staubo was appointed as our CEO in May 2021. Prior to this role he acted as Golar LNG's Chief Financial Officer from September 2020 and as CEO of Golar LNG Partners LP from May 2020 until the closing of the GMLP Merger. Mr. Staubo has 11 years of experience advising and investing in shipping, energy and infrastructure companies. Mr. Staubo worked in the Corporate Finance division of Clarkson's Platou Securities, including as Head of Shipping, from June 2010 until September 2018. Subsequent to his time at Clarkson's, Mr. Staubo has worked at Magni Partners Ltd, as a partner since October 2018. During his time with Magni Partners, Mr. Staubo has worked as an advisor to the Golar group and was extensively involved in the amendments to Golar Partners’ Norwegian Bonds. He has a MA in Business Studies and Economics from the University of Edinburgh.
Eduardo Maranhão was appointed as our Chief Financial Officer in May 2021. Prior to assuming this position Mr. Maranhão served as Chief Financial Officer of Hygo Energy Transition Ltd. Mr. Maranhão has also served as both CEO and as a director of Centrais Electricas de Sergipe S.A., and as a partner at Magni Partners. Mr. Maranhão has vast experience in international energy projects and infrastructure financing having worked at different financial institutions including Lakeshore Partners, Banco Santander, Crédit Agricole CIB, Banco Votorantim and Citibank. Mr. Maranhão holds a Bachelor of Business Administration from Universidade de Pernambuco in Brazil and has completed a Management Acceleration Programme from INSEAD in France.
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Øistein Dahl has served as the Managing Director of Golar Management Norway (previously Golar Wilhelmsen) since September 2011, the Chief Operating Officer of Golar Management since April 2012 until April 2022 and the Chief Operating Officer of CCMN from April 2022. From 2012 until the closing of the GMLP Merger, Mr. Dahl served as Chief Operating Officer of Golar Partners. Prior to September 2011, he worked for the Leif Höegh & Company Group (roll-on roll-off, tank, bulk, reefer general cargo and LNG vessels). He held various positions within the Höegh Group of companies within vessel management, newbuilds and projects, as well as business development before becoming President for Höegh Fleet in October 2007, a position he held for four years. Mr. Dahl has also worked within offshore engineering and with the Norwegian Class Society, DNV-GL. Mr. Dahl has a M.Sc degree from the NTNU Technical University in Trondheim, Norway.
Ragnar Nes joined Golar in November 2017 and was appointed the Chief Operating Officer of Golar Management in April 2022 after having served as the Head of FLNG since March 2018. Prior to joining Golar, Mr. Nes served as the operational manager and asset manager for the floating production storage and offloading vessels in Fred Olsen, Yinson and BW Offshore for 10 years. Prior to joining offshore oil and gas, Mr. Nes held various positions in ship management for Odfjell and Wilh.Wilhelmsen. Mr. Nes has also worked with Det Norske Veritas and started his career at sea as electrician onboard submarines in Royal Norwegian Navy. Mr. Nes has a MSc degree in Electrical Engineering from the NTNU Technical University in Trondheim, Norway.
Olve Skjeggedal joined Golar in April 2015. Prior to his appointment as Chief Technical Officer in September 2019 Mr. Skjeggedal served as Project Manager FLNG, and more recently as Project Director for the Golar Gimi FLNG conversion for the BP Phase 1 Greater Tortue Ahmeyim project. Prior to joining Golar, Mr. Skjeggedal held various positions within engineering, business development and project management in energy and gas related businesses including General Electric, Wärtsilä and Höegh LNG. Mr. Skjeggedal has a M.Sc degree from the NTNU Technical University in Trondheim, Norway.
B. Compensation
For the year ended December 31, 2021, we paid our directors and executive officers aggregate cash compensation (including bonus) of $2.9 million and an aggregate amount of $0.1 million for pension and retirement benefits. During the year ended December 31, 2021, we granted them 750,000 share options at a weighted average exercise price of $10.97 with an expiration date of 2024. For a description of our share based payment plan please refer to the section of this item entitled “E. Share Ownership - Share Based Payment Plan” below.
In addition to cash compensation, during 2021 we also recognized an expense of $1.6 million relating to share based compensation issued to certain of our directors and executive officers. See note 26 “Share Capital and Share Based Compensation” of our consolidated financial statements included herein.
C. Board Practices
Our directors do not have service contracts with us and do not receive any benefits upon termination of their directorships. Our board of directors established an audit committee in July 2005, which is responsible for overseeing the quality and integrity of our external financial reporting, appointment, compensation and oversight of our external auditors and oversees our management assessment of internal controls and procedures, as more fully set forth in its written charter, which has been adopted by the board. Our audit committee consists of three independent members, Lori Wheeler Naess, Daniel Rabun and Carl Steen, who are all Company directors. In addition, the board of directors also has compensation and nominations committees, details of which are further described in “Item 16G. Corporate Governance”.
Our board of directors is elected annually at the annual general meeting. Officers are appointed from time to time by our board of directors and hold office until a successor is elected.
As a foreign private issuer, we are exempt from certain Nasdaq requirements that are applicable to U.S. listed companies. Please see the section of this Annual Report entitled “Item 16G. Corporate Governance” for a discussion of how our corporate governance practices differ from those required of U.S. companies listed on the Nasdaq.
D. Employees
As of December 31, 2021, we employed approximately 300 employees and consultants in our offices in Bermuda, Cameroon, Croatia, London, Malaysia and Oslo, as well as in the shipyards where are vessel conversions are underway. We also employed approximately 1,403 seafaring employees and contractors for the vessels that we own and manage.
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E. Share Ownership
The table below shows the number and percentage of our issued and outstanding common shares beneficially owned by our directors and officers as of April 14, 2022. Also shown are their interests in share options and restricted stock units awarded to them under our various share based payment schemes. The subscription price for options granted under the schemes will normally be reduced by the amount of all dividends declared by us in the period from the date of grant until the date the option is exercised.

Director or Officer | Beneficial Ownership in Common Shares |  | Interest in Options |  |  |  | Restricted Stock Units
| Number of shares |  | % |  | Total number of options |  | Exercise price |  | Expiry date |  | Number of RSUs |  | Vesting Date
Tor Olav Trøim | 5,314,454(1) |  | 4.92% |  | 11,840 |  | $26.90 |  | 2023 |  | 5,563 |  | 2023
Daniel Rabun | * |  | * |  | 3,950 |  | $26.90 |  | 2023 |  | 2,225 |  | 2023
Thorleif Egeli | * |  | * |  | — |  | N/A |  | N/A |  | 2,225 |  | 2023
Carl Steen | * |  | * |  | 3,950 |  | $26.90 |  | 2023 |  | 2,225 |  | 2023
Niels Stolt-Nielsen | 2,741,470(2) |  | 2.47% |  | 3,950 |  | $26.90 |  | 2023 |  | 2,225(2) |  | 2023
Lori Wheeler Naess | * |  | * |  | 3,950 |  | $26.90 |  | 2023 |  | 2,225 |  | 2023
Georgina Sousa | * |  | * |  | — |  | N/A |  | N/A |  | N/A |  | N/A
Karl Fredrik Staubo | * |  | * |  | 500,000 |  | $10.97 |  | 2024 |  | N/A |  | N/A
Eduardo Maranhao | * |  | * |  | 250,000 |  | $10.97 |  | 2024 |  | N/A |  | N/A
Ragnar Nes | — |  | — |  | 4,300 |  | $26.90 |  | 2023 |  | 1,894 |  | 2023
Olve Skjeggedal | * |  | * |  | 3,200 |  | $26.90 |  | 2023 |  | 5,098 |  | 2023
|  |  |  |  |  |  |  |  |  |  | 8,261 |  | **

* Less than 1%.
** These are the maximum number of RSUs that may be earned under the award granted in March 2020 and which will vest in March 2023. The award is 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 ending December 31, 2022.
(1) 5,314,454 common shares are owned by Drew Holdings Limited, a company controlled by Tor Olav Trøim.
(2) Included within this balance are 2,672,695 shares which are owned by Stolt-Nielsen Limited, a company controlled by Niels Stolt-Nielsen. Shares will also be received by this company upon vesting of RSUs.
Our directors and executive officers have the same voting rights as all other holders of our common shares.
Share Based Payment Plan
Our Long Term Incentive Plan (the “LTIP”) was adopted by our board of directors, effective as of October 24, 2017. The purpose of the LTIP is primarily to provide a means through which we may attract, retain and motivate qualified persons as employees, directors and consultants. Accordingly, the LTIP provides for the grant of options and other awards as determined by the board of directors in its sole discretion.
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As of December 31, 2021, 0.7 million of our authorized and unissued common shares were reserved for issue pursuant to subscription under options and restricted stock units granted under our share based payment plans. For further detail on share options and restricted stock units please see note 26 “Share Capital and Share Based Compensation” of our consolidated financial statements included herein.
The exercise price of options is reduced by the value of dividends paid until 2019, on a per share basis. Accordingly, the above figures show the reduced exercise price as of April 14, 2022.
ITEM 7. MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS
A. Major shareholders
The following table presents certain information as of April 14, 2022 regarding the beneficial ownership of our common shares with respect to each shareholder that we know to beneficially own more than 5% of our issued and outstanding common shares:

|  | Common Shares (4)
Owner |  | Number | Percent
Orbis Investment Management Limited (1) |  | 11,747,447 |  | 10.88 | %
Cobas Asset Management (2) |  | 10,401,514 |  | 9.63 | %
Rubric Capital Management LP (3) |  | 6,800,187 |  | 6.30 | %

(1) Information derived from Schedule 13G/A of Orbis Investment Management Limited filed with the Commission on February 14, 2022.
(2) Information derived from Schedule 13G/A of Cobas Asset Management filed with the Commission on March 9, 2022.
(3) Information derived from Schedule 13G of Rubric Capital Management LP filed with the Commission on February 14, 2022.
(5) Based on a total of 107,988,209 outstanding shares of our common stock as of April 14, 2022.
Our major shareholders have the same voting rights as all of our other common shareholders. To our knowledge, no corporation or foreign government owns more than 50% of our issued and outstanding common shares. In 2021, Morgan Stanley and FMR LLC, reduced their shareholdings by 4.9% and 1.5% to 1.5% and 3.6%, respectively. In 2020, Luxor Capital Partners LP, reduced their shareholding by 3.5% to 1.7%. We are not aware of any arrangements the operation of which may, at a subsequent date, result in a change of control.
As of April 14, 2022, we had eight common shareholders of record located in the United States. One of those shareholders is CEDE & CO., a nominee of The Depository Trust Company, which held in aggregate 107,902,889 common shares, representing 99.87% of our outstanding common shares. We believe that the shares held by CEDE & CO. include common shares beneficially owned by both holders in the United Sates and non-U.S. beneficial owners.
B. Related party transactions
There are no provisions in our Memorandum of Association or Bye-Laws regarding related party transactions. The Bermuda Companies Act of 1981 provides that a company, or one of its subsidiaries, may enter into a contract with an officer of the company, or an entity in which an officer has a material interest, if the officer notifies the directors of his or her interest in the contract or proposed contract.
The related party transactions that we were party to between January 1, 2021 and December 31, 2021 are described in note 28 “Related Party Transactions” of our consolidated financial statements included herein.
C. Interests of Experts and Counsel
Not applicable.
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ITEM 8. FINANCIAL INFORMATION
A. Consolidated Financial Statements and Other Financial Information
See ''Item 18. Financial Statements''
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.
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. HMRC has been challenging the use of similar lease structures and has been engaged in litigation of a test case, with an unrelated party, for some years. In August 2015, following an appeal to the Court of Appeal by the HMRC which set aside previous judgments in favor of the tax payer, the First Tier Tribunal (“FTT or the UK court”) ruled in favor of HMRC. We have reviewed the details of the case and the basis of the judgment with our legal and tax advisers to ascertain what impact, if any, the judgment may have on us and the possible range of exposure. Our discussions with HMRC on this matter have concluded without agreement and, in January 2020, we received a closure notice to the inquiry stating the basis of HMRC's position. Consequently, a notice of appeal against the closure notice was submitted to HMRC. In December 2020, notice of appeal was submitted to the FTT Tribunal.
In April 2022, we entered into the settlement deed with HMRC in relation our UK tax lease benefits and paid $63.5 million, of which $16.0 million was funded from our restricted cash. See note 29 “Commitments and Contingencies” and note 30 “Subsequent Events” of our consolidated financial statements included herein for further details.
Dividend distribution policy
Our long-term objective is to pay a regular dividend in support of our main objective to provide significant returns to shareholders. The level of our dividends will be guided by current earnings, market prospects, capital expenditure requirements and investment opportunities.
Any future dividends declared will be at the discretion of our board of directors and will depend upon our financial condition, earnings and other factors, such as any restrictions in our financing arrangements. Our ability to declare dividends is also regulated by Bermuda law, which prohibits us from paying dividends if, at the time of distribution, we will not be able to pay our liabilities as they fall due or the value of our assets is less than the sum of our liabilities, issued share capital and share premium.
In addition, since we are a holding company with no material assets other than the shares of our subsidiaries and affiliates through which we conduct our operations, our ability to pay dividends will depend on our subsidiaries and affiliates distributing to us their earnings and cash flows. Some of our loan agreements limit or prohibit our and our subsidiaries' and affiliates' ability to make distributions to us without the consent of our lenders.
In 2022, we purchased and subsequently cancelled 0.4 million treasury shares. See item 16E. Purchases of equity securities by the issuer and affiliated purchasers and note 30 “Subsequent Events” for further details.
For 2021, there were no dividends declared. During 2021, we purchased and cancelled 2.0 million treasury shares. See note 26 “Share capital and share based compensation” of our consolidated financial statements included herein for further details.
For 2020, there were no dividends declared. In February 2020, we purchased the remaining 1.5 million of our shares underlying the Total Return Swap and subsequently cancelled all our treasury shares that we repurchased in the current and previous periods amounting to 3.5 million shares. See note 26 “Share capital and share based compensation” of our consolidated financial statements included herein for further details.
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For 2019, our board of directors declared quarterly dividends in May 2019 of $15.1 million, or $0.15 per share. The Board approved the suspension of further dividends to finance the repurchase of the 3 million shares underlying the Total Return Swap to simplify Golar’s capital structure, remove the cash collateral requirement and reduce earnings volatility.
B. Significant Changes
Significant changes since the date of our consolidated financial statements are discussed on Item 5, Operating and Financial Review and Prospects and further disclosed in note 30 “Subsequent Events” of our consolidated financial statements included herein.
ITEM 9. THE OFFER AND LISTING
C. Markets
Our common shares have traded on the Nasdaq since December 12, 2002 under the symbol “GLNG”. In March 2022, we listed our Norwegian bonds on the Oslo Børs.
ITEM 10. ADDITIONAL INFORMATION
This section summarizes our share capital and the material provisions of our Memorandum of Association and Bye-Laws, including rights of holders of our common shares. The description is only a summary and does not describe everything that our Memorandum of Association and Bye-laws contain. Our Memorandum of Association and the Bye-Laws have previously been filed as Exhibits 1.1 and 1.2, respectively to our Registration Statement on Form 20-F, (File No. 000-50113) filed with the Commission on November 27, 2002, and are hereby incorporated by reference into this Annual Report.
At our 2013 Annual General Meeting, our shareholders voted to amend our Bye-laws to ensure conformity with revisions to the Bermuda Companies Act 1981, as amended. We adopted these amended Bye-laws of the Company on September 20, 2013, and they were filed as Exhibit 3.1 to our report on Form 6-K filed with the Commission on July 1, 2014, and are hereby incorporated by reference into this Annual Report.
At our 2020 Annual General Meeting, our shareholders voted to further amend our Bye-laws to change the quorum necessary for the transaction of the company business. We adopted these amended Bye-laws of the Company on September 24, 2020, and they were filed as Exhibit 1.1 to our report on Form 6-K filed with the Commission on November 30, 2020, and are hereby incorporated by reference into this Annual Report.
A. Share capital
Not applicable.
B. Memorandum of Association and Bye-laws
The object of our business, as stated in Section Six of our Memorandum of Association, is to engage in any lawful act or activity for which companies may be organized under the Companies Act, 1981 of Bermuda, or the Companies Act, other than to issue insurance or re-insurance, to act as a technical advisor to any other enterprise or business or to carry on the business of a mutual fund. Our Memorandum of Association and Bye-laws do not impose any limitations on the ownership rights of our shareholders.
Shareholder Meetings. Under our Bye-laws, annual shareholder meetings will be held in accordance with the Companies Act at a time and place selected by our board of directors. The quorum at any annual or general meeting is equal to one or more shareholders, either present in person or represented by proxy, holding in the aggregate shares carrying 33 1/3% of the exercisable voting rights. Special meetings may be called at the discretion of the board of directors and at the request of shareholders holding at least one-tenth of all outstanding shares entitled to vote at a meeting. Annual shareholder meetings and special meetings must be called by not less than seven days' prior written notice specifying the place, day and time of the meeting. The board of directors may fix any date as the record date for determining those shareholders eligible to receive notice of and to vote at the meeting.
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The Companies Act provides that a company must have a general meeting of its shareholders in each calendar year. The Companies Act does not impose any general requirements regarding the number of voting shares which must be present or represented at a general meeting in order for the business transacted at the general meeting to be valid. The Companies Act generally leaves the quorum for shareholder meetings to the company to determine in its Bye-laws. The Companies Act specifically imposes special quorum requirements where the shareholders are being asked to approve the modification of rights attaching to a particular class of shares (33.33%) or an amalgamation or merger transaction (33.33%) unless in either case the Bye-laws provide otherwise. The Company's Bye-laws do not provide for a quorum requirement other than at least two members being present in person or by proxy and entitled to vote (whatever the number of shares held by them).
There are no limitations on the right of non-Bermudians or non-residents of Bermuda to hold or vote our common shares.
The key powers of our shareholders include the power to alter the terms of the Company's Memorandum of Association and to approve and thereby make effective any alterations to the Company's Bye-laws made by the directors. Dissenting shareholders holding 20% of the Company's shares may apply to the Court to annul or vary an alteration to the Company's Memorandum of Association. A majority vote against an alteration to the Company's Bye-laws made by the directors will prevent the alteration from becoming effective. Other key powers are to approve the alteration of the Company's capital including a reduction in share capital, to approve the removal of a director, to resolve that the Company be wound up or discontinued from Bermuda to another jurisdiction or to enter into an amalgamation or winding up. Under the Companies Act, all of the foregoing corporate actions require approval by an ordinary resolution (a simple majority of votes cast), except in the case of an amalgamation or merger transaction, which requires approval by 75% of the votes cast unless the Bye-Laws provide otherwise. The Company's Bye-laws only require an ordinary resolution to approve an amalgamation. In addition, the Company's Bye-laws confer express power on the board to reduce its issued share capital selectively with the authority of an ordinary resolution.
The Companies Act provides shareholders holding 10% of the Company's voting shares the ability to request that the board of directors shall convene a meeting of shareholders to consider any business which the shareholders wish to be discussed by the shareholders including (as noted below) the removal of any director. However, the shareholders are not permitted to pass any resolutions relating to the management of the Company's business affairs unless there is a pre-existing provision in the Company's Bye-laws which confers such rights on the shareholders. Subject to compliance with the time limits prescribed by the Companies Act, shareholders holding 20% of the voting shares (or alternatively, 100 shareholders) may also require the directors to circulate a written statement not exceeding 1000 words relating to any resolution or other matter proposed to be put before, or dealt with at, the annual general meeting of the Company.
Majority shareholders do not generally owe any duties to other shareholders to refrain from exercising all of the votes attached to their shares. There are no deadlines in the Companies Act relating to the time when votes must be exercised.
The Companies Act provides that a company shall not be bound to take notice of any trust or other interest in its shares. There is a presumption that all the rights attaching to shares are held by, and are exercisable by, the registered holder, by virtue of being registered as a member of the company. The company's relationship is with the registered holder of its shares. If the registered holder of the shares holds the shares for someone else (the beneficial owner) then if the beneficial owner is entitled to the shares, the beneficial owner may give instructions to the registered holder on how to vote the shares. The Companies Act provides that the registered holder may appoint more than one proxy to attend a shareholder meeting, and consequently where rights to shares are held in a chain, the registered holder may appoint the beneficial owner as the registered holder's proxy.
Directors. The Companies Act provides that the directors shall be elected or appointed by the shareholders. A director may be elected by a simple majority vote of shareholders, at a meeting where shareholders holding not less than 33.33% of the voting shares are present in person or by proxy. A person holding 50% or more of the voting shares of the Company will be able to elect all of the directors, and to prevent the election of any person whom such shareholder does not wish to be elected. There are no provisions for cumulative voting in the Companies Act or the Bye-laws and the Company's Bye-laws do not contain any super-majority voting requirements. The appointment and removal of directors is covered by Bye-laws 86, 87 and 88.
There are procedures for the removal of one or more of the directors by the shareholders before the expiration of his term of office. Shareholders holding 10% or more of the voting shares of the Company may require the board of directors to convene a shareholder meeting to consider a resolution for the removal of a director. At least 14 days’ written notice of a resolution to remove a director must be given to the director affected, and that director must be permitted to speak at the shareholder meeting at which the resolution for his removal is considered by the shareholders.
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The Companies Act stipulates that an undischarged bankruptcy of a director (in any country) shall prohibit that director from acting as a director, directly or indirectly, and taking part in or being concerned with the management of a company, except with leave of the court. The Company's Bye-Law 89 is more restrictive in that it stipulates that the office of a Director shall be vacated upon the happening of any of the following events (in addition to the Director's resignation or removal from office by the shareholders):
•If he becomes of unsound mind or a patient for any purpose of any statute or applicable law relating to mental health and the Board resolves that he shall be removed from office;
•If he becomes bankrupt or compounds with his creditors;
•If he is prohibited by law from being a Director; or
•If he ceases to be a Director by virtue of the Companies Act.
Under the Company's Bye-laws, the minimum number of directors comprising the board of directors at any time shall be two. The board of directors currently consists of seven directors. The quorum necessary for the transaction of business of the board may be fixed by the board and shall constitute a majority of the board. The minimum and maximum number of directors comprising the board of directors from time to time shall be determined by way of an ordinary resolution of the shareholders of the Company. The shareholders may, at the annual general meeting by ordinary resolution, determine that one or more vacancies in the board of directors be deemed casual vacancies. The board of directors, so long as a quorum remains in office, shall have the power to fill such casual vacancies. Each director will hold office until the next annual general meeting or until his successor is appointed or elected. The shareholders may call a Special General Meeting for the purpose of removing a director, provided notice is served upon the concerned director 14 days prior to the meeting and he is entitled to be heard. Any vacancy created by such a removal may be filled at the meeting by the election of another person by the shareholders or in the absence of such election, by the board of directors.
Subject to the provisions of the Companies Act, a director of a company may, notwithstanding his office, be a party to or be otherwise interested in any transaction or arrangement with that company, and may act as director, officer, or employee of any party to a transaction in which the company is interested. Under our Bye-Law 92, provided an interested director declares the nature of his or her interest immediately or thereafter at a meeting of the board of directors, or by writing to the directors as required by the Companies Act, a director shall not by reason of his office be held accountable for any benefit derived from any outside office or employment. The vote of an interested director, provided he or she has complied with the provisions of the Companies Act and our Bye-Laws with regard to disclosure of his or her interest, shall be counted for purposes of determining the existence of a quorum.
The Company’s Bye-law 94 provides the board of directors with the authority to exercise all of the powers of the Company to borrow money and to mortgage or charge all or any part of our property and assets as collateral security for any debt, liability or obligation. The Company’s directors are not required to retire because of their age, and the directors are not required to be holders of the Company’s common shares. Directors serve for a one year term, and shall serve until re-elected or until their successors are appointed at the next annual general meeting. The Company’s Bye-laws provide that no director, alternate director, officer or member of a committee, if any, resident representative, or his heirs, executors or administrators, whom we refer to collectively as an indemnitee, is liable for the acts, receipts, neglects or defaults of any other such person or any person involved in our formation, or for any loss or expense incurred by us through the insufficiency or deficiency of title to any property acquired by us, or for the insufficiency or deficiency of any security in or upon which any of our monies shall be invested, or for any loss or damage arising from the bankruptcy, insolvency, or tortuous act of any person with whom any monies, securities, or effects shall be deposited, or for any loss occasioned by any error of judgment, omission, default, or oversight on his part, or for any other loss, damage or misfortune whatever which shall happen in relation to the execution of his duties, or supposed duties, to us or otherwise in relation thereto. Each indemnitee will be indemnified and held harmless out of our funds to the fullest extent permitted by Bermuda law against all liabilities, loss, damage or expense (including but not limited to liabilities under contract, tort and statute or any applicable foreign law or regulation and all reasonable legal and other costs and expenses properly payable) incurred or suffered by him as such director, alternate director, officer, committee member or resident representative (or in his reasonable belief that he is acting as any of the above). In addition, each indemnitee shall be indemnified against all liabilities incurred in defending any proceedings, whether civil or criminal, in which judgment is given in such indemnitee’s favor, or in which he is acquitted or in connection with any application under the Companies Act in which relief from liability is granted to him by the court. The Company is authorized to purchase insurance to cover any liability it may incur under the indemnification provisions of its Bye-laws. The indemnity provisions are covered by Bye-laws 138 through 146.
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Dividends. Holders of common shares are entitled to receive dividend and distribution payments, pro rata based on the number of common shares held, when, as and if declared by the board of directors, in its sole discretion. Any future dividends declared will be at the discretion of the board of directors and will depend upon our financial condition, earnings and other factors.
As a Bermuda exempted company, we are subject to Bermuda law relating to the payment of dividends. We may not pay any dividends if, at the time the dividend is declared or at the time the dividend is paid, there are reasonable grounds for believing that, after giving effect to that payment;
•we will not be able to pay our liabilities as they fall due; or
•the realizable value of our assets is less than our liabilities.
In addition, since we are a holding company with no material assets, and conduct our operations through subsidiaries and our affiliates, our ability to pay any dividends to shareholders will depend on our subsidiaries' and affiliates distributing to us their earnings and cash flow. Some of our loan agreements currently limit or prohibit our subsidiaries' ability to make distributions to us and our ability to make distributions to our shareholders.
Share repurchases and preemptive rights. Subject to certain balance sheet restrictions, the Companies Act permits a company to purchase its own shares if it is able to do so without becoming cash flow insolvent as a result. The restrictions are that the par value of the share must be charged against the company's issued share capital account or a company fund which is available for dividend or distribution or be paid for out of the proceeds of a fresh issue of shares. Any premium paid on the repurchase of shares must be charged to the company's current share premium account or charged to a company fund which is available for dividend or distribution. The Companies Act does not impose any requirement that the directors shall make a general offer to all shareholders to purchase their shares pro rata to their respective shareholdings. The Company's Bye-Laws do not contain any specific rules regarding the procedures to be followed by the Company when purchasing its own shares, and consequently the primary source of the Company's obligations to shareholders when the Company tenders for its shares will be the rules of the listing exchanges on which the Company's shares are listed. The Company’s power to purchase its own shares is covered by Bye-laws 9, 10 and 11.
The Companies Act does not confer any rights of pre-emption on shareholders when a company issues further shares, and no such rights of pre-emption are implied as a matter of common law. The Company's Bye-Laws do not confer any rights of pre-emption. Bye-Law 8 specifically provides that the issuance of more shares ranking pari passu with the shares in issue shall not constitute a variation of class rights, unless the rights attached to shares in issue state that the issuance of further shares shall constitute a variation of class rights. Bye-Law 12 confers on the directors the right to dispose of any number of unissued shares forming part of the authorized share capital of the Company without any requirement for shareholder approval. The Company’s power to issue shares is covered by Bye-laws 12, 13, 14, and 15.
Liquidation. In the event of our liquidation, dissolution or winding up, the holders of common shares are entitled to share in our assets, if any, remaining after the payment of all of our debts and liabilities, subject to any liquidation preference on any outstanding preference shares.
C. Material contracts
The following is a list of each material contract, other than material contracts entered into in the ordinary course of business, to which we or any of our subsidiaries is a party, for the two years immediately preceding the date of this Annual Report.
1.Rules of Golar LNG Limited Bermuda Employee Share Option Scheme.
2.Bermuda Tax Assurance, dated May 23, 2011.
3.Memorandum of Agreement, dated September 9, 2015, by and between Golar Hilli Corporation and Fortune Lianjiang Shipping S.A.
4.Bareboat charter by and between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A., dated September 9, 2015.
5.Additional Clauses to the Bareboat Charter Party dated September 9, 2015 between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A.
6.Common Terms Agreements, by and between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A., dated September 9, 2015.
7.Share Purchase Agreement, dated June 17, 2016, by and between Golar LNG and Stonepeak Infrastructure Fund II Cayman (G) Ltd.
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8.Investment and Shareholders Agreement, dated July 5, 2016, by and among Golar LNG Limited, Stonepeak Infrastructure Fund II Cayman (G) Ltd and Golar Power Limited.
9.Second Amended and Restated Agreement of Limited Partnership of Golar LNG Partners LP dated October 19, 2016.
10.Indenture, dated February 17, 2017, between Golar LNG Limited and Deutsche Bank Trust Company Americas as a Bond Trustee.
11.Purchase and Sale Agreement, dated August 15, 2017, by and among Golar LNG Limited, KS Investments Pte. Ltd., Black & Veatch International Company and Golar Partners Operating LLC.
12.2017 Long-Term Incentive Plan.
13.Liquefaction Tolling Agreement, dated November 29, 2017, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
14.First Amendment to Liquefaction Tolling Agreement, dated November 15, 2019, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
15.Second Amendment to Liquefaction Tolling Agreement, dated March 23, 2021, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
16.Third Amendment to Liquefaction Tolling Agreement, dated July 22, 2021, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
17.Amendment Agreement, dated March 23, 2018, relating to the Purchase and Sale Agreement by and between Golar LNG Partners LP, Golar LNG Limited, KS Investments Pte. Ltd. and Black & Veatch International Company.
18.Amended and Restated Limited Liability Company Agreement of Golar Hilli LLC, dated July 12, 2018.
19.Amended and Restated Limited Liability Company Agreement of Golar Hilli LLC dated as of April 15, 2021, by and among Golar LNG Limited, Golar Partners Operating LLC, KSI Investments Pte. Ltd. and Black & Veatch International Corporation.
20.Golar LNG Partners LP Guarantee Agreement, dated as of July 12, 2018.
21.Lease and Operate Agreement, dated February 26, 2019, by and between Gimi MS Corporation and BP Mauritania Investments Limited.
22.$700 million facility agreement dated October 24, 2019, by and between Gimi MS Corporation, ABN Amro Bank N.V., Clifford Capital Pte. Ltd., ING Bank N.V. and Natixis.
23.First supplemental agreement to $700 million facility dated January 19, 2021, by and among Gimi MS Corporation, Golar LNG Limited, Gimi Holding Company Limited and ING Bank N.V.
24.Second supplemental agreement to $700 million facility agreement dated March 02, 2021, by and between Gimi MS Corporation, ABN Amro Bank N.V., Clifford Capital Pte. Ltd., ING Bank N.V. and Natixis.
25.Agreement and plan of Merger dated January 13, 2021 between Golar LNG Partners LP, Golar GP LLC, New Fortress Energy Inc, Lobos Acquisition LLC and NFE International Holdings Limited.
26.Transfer Agreement, dated as of January 13, 2021, by and between Golar LNG Limited, Golar GP LLC and NFE International Holdings Limited.
27.Support Agreement, dated as of January 13, 2021, by and between Golar LNG Partners LP, Golar LNG Limited, Golar LNG Partners LP and Golar GP LLC.
28.Agreement and plan of Merger dated January 13, 2021 between Hygo Energy Transition Ltd, New Fortress Energy Inc, Golar LNG Limited, Stonepeak Infrastructure Fund II Cayman (G) Ltd and Lobos Acquisition LLC.
29.Omnibus Agreement dated as of April 15, 2021, by and among Golar LNG Limited, certain direct and indirect subsidiaries of Golar LNG Limited and New Fortress Energy, Inc.
30.Omnibus Agreement (Hygo) dated as of April 15, 2021 by and among Golar LNG Limited, certain direct and indirect subsidiaries of Golar LNG Limited party thereto and New Fortress Energy Inc.
31.Shareholders’ Agreement dated as of April 15, 2021 by and among New Fortress Energy Inc., Golar LNG Limited and Stonepeak Infrastructure Fund II Cayman (G) Ltd.
32.$300 million unsecured Nowegian Bond dated March 10, 2012, by and between Golar LNG Limited, DNB Bank ASA, Danske Bank A/S, Pareto Securiities AS and Nordea Bank Abp.
33.Share purchase agreement dated dated January 26, 2022 by and between Cool Company Ltd and Golar LNG Limited.
34.Amendment agreement to share purchase agreement dated February 25, 2022 by and between Cool Company Ltd and Golar LNG Limited.
For a further discussion of these contracts and the related transactions, please refer to “Item 4. Information on the Company-A. History and Development of the Company,” “Item 4. Information on the Company-B. Business Overview,” “Item 5. Operating and Financial Review and Prospects A. Operating Results,” “Item 5. Operating and Financial Review and Prospects-B. Liquidity and Capital Resources,” “Item 6. Directors, Senior Management and Employees E. Share Ownership,” “Item 7. Major Shareholders and Related Party Transactions-B. Related Party Transactions” and “Item 10. Additional Information--E. Taxation.” Other than as discussed in this Annual Report, we have no material contracts, other than contracts entered into in the ordinary course of business, to which we or any of our subsidiaries are a party.
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D. Exchange Controls
The Bermuda Monetary Authority, or the BMA, must give permission for all issuances and transfers of securities of a Bermuda exempted company like us, unless the proposed transaction is exempted by the BMA's written general permissions. We have received a general permission from the BMA to issue any unissued common shares, and for the free transferability of the common shares as long as our common shares are listed on the Nasdaq. Our common shares may therefore be freely transferred among persons who are residents or non-residents of Bermuda.
Although we are incorporated in Bermuda, we are classified as non-resident of Bermuda for exchange control purposes by the BMA. Other than transferring Bermuda Dollars out of Bermuda, there are no restrictions on our ability to transfer funds into or out of Bermuda to pay dividends to U.S. residents who are holders of our common shares or other non-resident holders of our common shares in currency other than Bermuda Dollars.
E. Taxation
The following is a discussion of the material U.S. federal income tax and Bermuda tax considerations relevant to a U.S. Holder, as defined below, of our common stock. This discussion does not purport to deal with the tax consequences of owning our common stock to all categories of investors, some of which, such as financial institutions, regulated investment companies, real estate investment trusts, tax-exempt organizations, insurance companies, persons holding our common stock as part of a hedging, integrated, conversion or constructive sale transaction or a straddle, traders in securities that have elected the mark-to-market method of accounting for their securities, persons liable for alternative minimum tax, persons who are investors in partnerships or other pass-through entities for U.S. federal income tax purposes, dealers in securities or currencies, U.S. Holders whose functional currency is not the U.S. dollar, persons required to recognize income for U.S. federal income tax purposes no later than when such income is included on an “applicable financial statement,” persons subject to the “base-erosion and anti-avoidance” tax and investors that own, actually or under applicable constructive ownership rules, 10% or more (by vote or value) of our shares of common stock, may be subject to special rules. This discussion deals only with holders who hold the shares of our common stock as a capital asset. You are encouraged to consult your own tax advisors concerning the overall tax consequences arising in your own particular situation under U.S. federal, state, local or foreign law of the ownership of our common stock.
Taxation of Operating Income
U.S. Taxation of our Company
Shipping income that is attributable to transportation that begins or ends, but that does not both begin and end, in the United States will be considered to be 50% derived from sources within the United States. Shipping income attributable to transportation that both begins and ends in the United States will be considered to be 100% derived from sources within the United States. We are not permitted by law to engage in transportation that gives rise to 100% U.S. source income.
Shipping income attributable to transportation exclusively between non-U.S. ports will be considered to be 100% derived from sources outside of the United States. Shipping income derived from sources outside of the United States will not be subject to U.S. federal income tax.
Unless exempt from U.S. federal income tax under section 883 of the Code, we will be subject to U.S. federal income tax, in the manner discussed below, to the extent our shipping income is derived from sources within the United States.
Based upon our current and anticipated shipping operations, our vessels are and will be operated in various parts of the world, including to or from U.S. ports.
Application of Section 883 of the Code
We have made special U.S. federal tax elections in respect of all our vessel-owning or vessel-operating subsidiaries that are potentially subject to U.S. federal income tax on shipping income derived from sources within the United States. The effect of such elections is to disregard the subsidiaries for which such elections have been made as separate taxable entities for U.S. federal income tax purposes.
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Under section 883 of the Code and the Treasury Regulations promulgated thereunder, we, and each of our subsidiaries, will be exempt from U.S. federal income taxation on our respective U.S. source shipping income if the following three conditions are met:
•we and each subsidiary are organized in a jurisdiction outside the United States that grants an equivalent exemption from tax to corporations organized in the United States with respect to the types of U.S. source international transportation income that we earn (or an equivalent exemption);
•we satisfy the publicly traded test or the qualified shareholder stock ownership test as described in the Section 883 Regulations; and
•we meet certain substantiation, reporting and other requirements.
The U.S. Treasury Department has recognized (i) Bermuda, our country of incorporation, and (ii) the countries of incorporation of each of our subsidiaries that has earned shipping income from sources within the United States as qualified foreign countries. Accordingly, we and each such subsidiary satisfy the country of organization requirement.
Due to the public nature of our shareholdings, we do not believe that we will be able to substantiate that we satisfy the ownership requirement. However, as described below, we believe that we will be able to satisfy the publicly-traded requirement.
The Treasury Regulations under section 883 of the Code provide that the stock of a foreign corporation will be considered to be “primarily traded” on an “established securities market” if the number of shares of each class of stock that are traded during any taxable year on all “established securities markets” in that country exceeds the number of shares in each such class that are traded during that year on “established securities markets” in any other single country. Our stock was “primarily traded” on the Nasdaq, an “established securities market” in the United States, during 2021.
Under the Treasury Regulations, our common stock will be considered to be “regularly traded” on an “established securities market” if one or more classes of our stock representing more than 50% of our outstanding shares, by total combined voting power of all classes of stock entitled to vote and total value, is listed on the market; this is also known as the “Listing Requirement”. Since our common shares are listed on the Nasdaq, we will satisfy the Listing Requirement.
The Treasury Regulations further require that with respect to each class of stock relied upon to meet the Listing Requirement: (i) such class of stock is traded on the market, other than in minimal quantities, on at least 60 days during the taxable year or one-sixth of the days in a short taxable year; this is also known as the “Trading Frequency Test”; and (ii) the aggregate number of shares of such class of stock traded on such market is at least 10% of the average number of shares of such class of stock outstanding during such year, or as appropriately adjusted in the case of a short taxable year; this is also known as the “Trading Volume Test.” We believe that our common shares satisfied the Trading Frequency Test and the Trading Volume Test in 2021. Even if this were not the case, the Treasury Regulations provide that the Trading Frequency Test and the Trading Volume Test will be deemed satisfied by a class of stock if, as we expect to be the case with our common shares, such class of stock is traded on an “established securities market” in the United States and such class of stock is regularly quoted by dealers making a market in such stock.
Notwithstanding the foregoing, the Treasury Regulations provide that our common shares will not be considered to be “regularly traded” on an “established securities market” for any taxable year in which 50% or more of the outstanding common shares, by vote and value, are owned, for more than half the days of the taxable year, by persons who each own 5% or more of the vote and value of the outstanding common shares; this is also known as the “5% Override Rule.” The 5% Override Rule will not apply, however, if in respect of each category of shipping income for which exemption is being claimed, we can establish that individual residents of qualified foreign countries, or “Qualified Shareholders,” own sufficient common shares to preclude non-Qualified Shareholders from owning 50% or more of the total vote and value of our common shares for more than half the number of days during the taxable year; this is also known as the “5% Override Exception.”
Based on our public shareholdings for 2021, we were not subject to the 5% Override Rule for 2021. Therefore, we believe that we satisfied the Publicly-Traded Requirement for 2021 and we and each of our subsidiaries are entitled to exemption from U.S. federal income tax under section 883 of the Code in respect of our U.S. source shipping income. To the extent that we become subject to the 5% Override Rule in future years (as a result of changes in the ownership of our common shares), it may be difficult for us to establish that we qualify for the 5% Override Exception.
If we were not eligible for the exemption under section 883 of the Code, our U.S. source shipping income would be subject to U.S. federal income tax as described in more detail below.
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Taxation in Absence of Exemption Under Section 883 of the Code
To the extent the benefits of section 883 of the Code are unavailable with respect to any item of U.S. source shipping income earned by us or by our subsidiaries and such U.S. source shipping income is not considered to be “effectively connected” with the conduct of a U.S. trade or business, such U.S. source shipping income would be subject to a 4% U.S. federal income tax imposed by section 887 of the Code on a gross basis, without benefit of deductions. Since under the sourcing rules described above, no more than 50% of the shipping income earned by us or our subsidiaries would be derived from U.S. sources, the maximum effective rate of U.S. federal income tax on such gross shipping income would never exceed 2%. For the calendar year 2021, we and our subsidiaries would be subject to no aggregated tax under section 887 of the Code if applicable.
In addition, our U.S. source shipping income that is considered to be “effectively connected” with the conduct of a U.S. trade or business (net of applicable deductions) is subject to the U.S. corporate income tax currently imposed at a rate of 21%. In addition, we may be subject to the 30% U.S. “branch profits” tax on earnings effectively connected with the conduct of such trade or business, as determined after allowance for certain adjustments, and on certain interest paid or deemed paid attributable to the conduct of our U.S. trade or business.
Our U.S. source shipping income would be considered effectively connected with the conduct of a U.S. trade or business only if:
•we had, or were considered to have, a fixed place of business in the United States involved in the earning of our U.S. source shipping income; and
•substantially all of our U.S. source shipping income was attributable to regularly scheduled transportation, such as the operation of a ship that followed a published schedule with repeated sailings at regular intervals between the same points for voyages that begin or end in the United States.
We believe that we will not meet these conditions because we will not have, or permit circumstances that would result in having, such a fixed place of business in the United States or any ship sailing to or from the United States on a regularly scheduled basis.
Gain on Sale of Vessels
If we and our subsidiaries qualify for exemption from tax under section 883 of the Code in respect of our U.S. source shipping income, the gain on the sale of any vessel earning such U.S. source shipping income should likewise be exempt from U.S. federal income tax. Even if we and our subsidiaries are unable to qualify for exemption from tax under section 883 of the Code and we or any of our subsidiaries, as the seller of such vessel, is considered to be engaged in the conduct of a U.S. trade or business, gain on the sale of such vessel would not be subject to U.S. federal income tax provided the sale is considered to occur outside of the United States under U.S. federal income tax principles. In general, a sale of a vessel will be considered to occur outside of the United States for this purpose if title to the vessel, and risk of loss with respect to the vessel, pass to the buyer outside of the United States. To the extent circumstances permit, we intend to structure sales of our vessels in such a manner, including effecting the sale and delivery of vessels outside of the United States. If the sale is considered to occur within the United States, any gain on such sale may be subject to U.S. federal income tax as “effectively connected” income.
U.S. Taxation of U.S. Holders
The term “U.S. Holder” means a beneficial owner of our common shares that is a U.S. citizen or resident, U.S. corporation or other U.S. entity taxable as a corporation, an estate, the income of which is subject to U.S. federal income tax regardless of its source, or a trust if a court within the United States is able to exercise primary jurisdiction over the administration of the trust and one or more U.S. persons have the authority to control all substantial decisions of the trust, and owns our common shares as a capital asset, generally, for investment purposes.
If a partnership holds our common shares, the tax treatment of a partner will generally depend upon the status of the partner and upon the activities of the partnership. If you are a partner in a partnership holding our common shares, you are urged to consult your tax advisor.
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Distributions
Any distributions made by us with respect to our common shares to a U.S. Holder will generally constitute dividends to the extent of our current and accumulated earnings and profits, as determined under U.S. federal income tax principles. Subject to the discussion below under “Passive Foreign Investment Company”, we expect that dividends paid by us to a non-corporate U.S. Holder will be eligible for preferential U.S. federal income tax rates provided that the non-corporate U.S. Holder has owned the common shares for more than 60 days in the 121-day period beginning 60 days before the date on which our common shares becomes ex-dividend and certain other conditions are satisfied. However, there is no assurance that any dividends paid by us will be eligible for these preferential tax rates in the hands of a non-corporate U.S. Holder. Any dividends paid by us, which are not eligible for these preferential tax rates will be taxed as ordinary income to a non-corporate U.S. Holder. Because we are not a U.S. corporation, U.S. Holders that are corporations will generally not be entitled to claim a dividends-received deduction with respect to any distributions they receive from us. Dividends paid on our common shares will be income from sources outside the United States and will generally constitute “passive category income” or, in the case of certain U.S. Holders, “general category income” for U.S. foreign tax credit limitation purposes.
Distributions in excess of our earnings and profits will be treated first as a non-taxable return of capital to the extent of the U.S. Holder's tax basis in its common shares, and thereafter as a taxable capital gain.
Sale, Exchange or other Disposition of Our Common Shares
Subject to the discussion below under “Passive Foreign Investment Company,” a U.S. Holder generally will recognize taxable gain or loss upon a sale, exchange or other disposition of our common shares in an amount equal to the difference between the amount realized by the U.S. Holder from such sale, exchange or other disposition and the U.S. Holder's tax basis in the common shares. Such gain or loss will be treated as long-term capital gain or loss if the U.S. Holder's holding period in such common shares is greater than one year at the time of the sale, exchange or other disposition. Otherwise, such gain or loss will be treated as short-term capital gain or loss. A U.S. Holder's ability to deduct capital losses is subject to certain limitations. A U.S. Holder's gain or loss will generally be treated (subject to certain exceptions) as gain or loss from source within the United States for U.S. foreign tax credit limitation purposes.
Passive Foreign Investment Company
Notwithstanding the above rules regarding distributions and dispositions, special rules may apply to U.S. Holders (or, in some cases, U.S. persons who are treated as owning our common shares under constructive ownership rules) if we are treated as a “passive foreign investment company”, or a PFIC for U.S. federal income tax purposes. We will be a PFIC if either:
•at least 75% of our gross income in a taxable year is “passive income;” or
•at least 50% of our assets in a taxable year (averaged over the year and generally determined based upon value) are held for the production of, or produce, “passive income.”
For purposes of determining whether we are a PFIC, we will be treated as earning and owning our proportionate share of the income and assets, respectively, of (i) any of our subsidiary corporations in which we own 25% or more of the value of the subsidiary's stock and (ii) any partnership in which we either own 25% or more of the equity interests (by value) or satisfy an “active partner” test and do not elect out of “look through” treatment for the partnership. To date, our subsidiaries and we have derived most of our income from time and voyage charters (including through our interest in the Cool Pool), and we expect to continue to do so. This income should be treated as services income, which is not “passive income” for PFIC purposes. We believe there is substantial legal authority supporting our position consisting of case law and U.S. Internal Revenue Service, also known as the “IRS”, pronouncements concerning the characterization of income derived from time charters and voyage charters as services income for other tax purposes. However, there is also authority which characterizes time charter income as rental income rather than services income for other tax purposes.
Based on the foregoing, we believe that we were not a PFIC with respect to 2021 or any prior taxable year. However, the IRS or a court could disagree with our position. Further there can be no assurance that we will not become a PFIC any future taxable year as a result of changes in our operations or assets.
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If we become a PFIC (and regardless of whether we remain a PFIC), each U.S. Holder who owns or is treated as owning our common shares during any period in which we are so classified, would be subject to U.S. federal income tax, at the then highest applicable income tax rates on ordinary income, plus interest, upon certain “excess distributions” and upon dispositions of our common shares including, under certain circumstances, a disposition pursuant to an otherwise tax free reorganization, as if the distribution or gain had been recognized ratably over the U.S. Holder's entire holding period of our common shares. The amounts allocated to the taxable year of the sale or other disposition and to any year during such holding period before we became a PFIC would be taxed as ordinary income. An “excess distribution” generally includes dividends or other distributions received from a PFIC in any taxable year of a U.S. Holder to the extent that the amount of those distributions exceeds 125% of the average distributions made by the PFIC during a specified base period. The tax at ordinary rates and interest resulting from an excess distribution would not be imposed if the U.S. Holder makes a “mark-to-market” election or “qualified electing fund” election, as discussed below.
If we become a PFIC and, provided that, as is currently the case, our common shares are treated as “marketable stock,” a U.S. Holder may make a “mark-to-market” election with respect to our common shares. Under this election, any excess of the fair market value of the common shares at the close of any tax year over the U.S. Holder's adjusted tax basis in the common shares is included in the U.S. Holder's income as ordinary income. In addition, the excess, if any, of the U.S. Holder's adjusted tax basis at the close of any taxable year over the fair market value of the common shares is deductible in an amount equal to the lesser of the amount of the excess or the net “mark-to-market” gains that the U.S. Holder included in income in previous years. If a U.S. Holder makes a “mark-to-market” election after the beginning of its holding period of our common shares, the U.S. Holder does not avoid the PFIC rules described above with respect to the inclusion of ordinary income, and the imposition of interest thereon, attributable to periods before the election.
In some circumstances, a shareholder in a PFIC may avoid the unfavorable consequences of the PFIC rules by making a “qualified electing fund” election. However, a U.S. Holder cannot make a “qualified electing fund” election with respect to us unless such U.S. Holder complies with certain reporting requirements. We do not intend to provide the information necessary to meet such reporting requirements.
In addition to the above consequences, if we are or have been a PFIC for any taxable year, a U.S. Holder would be required to file IRS form 8621 with the IRS for that year with respect to such U.S. Holder's common stock.
U.S. Federal Income Tax Consequences to Non-U.S. Holders of Our Common Shares
A beneficial owner of our common shares (other than a partnership) that is not a U.S. Holder is referred to herein as a Non-U.S. Holder. It is assumed for purposes of this section that the Non-U.S. Holder (1) is not engaged in the conduct of a United States trade or business and (2) (a) if an individual, is not treated as a U.S. resident pursuant to the substantial presence test (generally treating a non-resident individual alien as a resident if such person is present in the United States for more than a weighted sum of 183 days during a three-year period and the nonresident alien is present for at least 31 days in the current year) and is not present in the United States for 183 days or more in the taxable year of disposition of the notes or common shares or (b) if not a natural person, has not made any election to subject itself to, or is otherwise subject to, U.S. federal income taxation on a net basis.
Subject to the discussion below regarding backup withholding, a Non-U.S. Holder will generally not be subject to U.S. federal income tax upon receipt, holding, or sale or disposition of, or receipt of dividends paid in respect of, the common shares.
Backup Withholding and Information Reporting
In general, dividend payments, or other taxable distributions, made within the United States will be subject to information reporting requirements. Such payments will also be subject to “backup withholding” if made to a non-corporate U.S. Holder and such U.S. Holder:
•fails to provide an accurate taxpayer identification number;
•provides us with an incorrect taxpayer identification number;
•is notified by the IRS that it has failed to report all interest or dividends required to be shown on its U.S. federal income tax returns; or
•in certain circumstances, fails to comply with applicable certification requirements.
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If a shareholder sells our common shares to or through a U.S. office or broker, the payment of the proceeds is subject to both U.S. information reporting and “backup withholding” unless the shareholder establishes an exemption. If the shareholder sells our common shares through a non-U.S. office of a non-U.S. broker and the sales proceeds are paid to the shareholder outside the United States, then information reporting and “backup withholding” generally will not apply to that payment. However, U.S. information reporting requirements, but not “backup withholding,” will apply to a payment of sales proceeds, including a payment made to a shareholder outside the United States, if the shareholder sells the common shares through a non-U.S. office of a broker that is a U.S. person or has some other contacts with the United States.
“Backup withholding” is not an additional tax. Rather, a taxpayer generally may obtain a refund of any amounts withheld under “backup withholding” rules that exceed such taxpayer's U.S. federal income tax liability by filing a refund claim with the IRS, provided that the required information is furnished to the IRS.
Individuals who are U.S. Holders (and to the extent specified in the applicable Treasury Regulations, certain individuals who are non-U.S. Holders and certain U.S. entities) who hold “specified foreign financial assets” (as defined in Section 6038D of the Code and the applicable Treasury Regulations) are required to file IRS Form 8938 (Statement of Specified Foreign Financial Assets) with information relating to each such asset for each taxable year in which the aggregate value of all such assets exceeds $75,000 at any time during the taxable year or $50,000 on the last day of the taxable year. Specified foreign financial assets would include, among other assets, our common stock, unless the common stock were held through an account maintained with a U.S. financial institution. Substantial penalties apply to any failure to timely file IRS Form 8938, unless the failure is shown to be due to reasonable cause and not due to willful neglect. Additionally, the statute of limitations on the assessment and collection of U.S. federal income tax with respect to a taxable year for which the filing of IRS Form 8938 is required may not close until three years after the date on which IRS Form 8938 is filed. U.S. Holders (including U.S. entities) and non-U.S. Holders are encouraged to consult their own tax advisors regarding their reporting obligations under Section 6038D of the Code.
Bermuda Taxation
Bermuda currently imposes no tax (including a tax in the nature of an income, estate, duty, inheritance, capital transfer or withholding tax) on profits, income, capital gains or appreciations derived by us, or dividends or other distributions paid by us to shareholders of our common shares. Bermuda has undertaken not to impose any such Bermuda taxes on shareholders of our common shares prior to the year 2035, except in so far as such tax applies to persons ordinarily resident in Bermuda.
The Minister of Finance in Bermuda has granted us a tax exempt status until March 31, 2035, under which no income taxes or other taxes (other than duty on goods imported into Bermuda and payroll tax in respect of any Bermuda-resident employees) are payable by us in Bermuda. If the Minister of Finance in Bermuda does not grant a new exemption or extension of the current tax exemption, and if the Bermudian Parliament passes legislation imposing taxes on exempted companies, we may become subject to taxation in Bermuda after March 31, 2035.
F. Dividends and Paying Agents
Not applicable.
G. Statements by Experts
Not applicable.
H. Documents on Display
We will file reports and other information with the Commission. The Commission maintains a website (http://www.sec.gov) that contains reports, proxy and information statements and other information regarding registrants that file electronically with it.
I. Subsidiary Information
Not applicable.
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ITEM 11. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to various market risks, including interest rate, commodity price and foreign currency exchange risks. We enter into a variety of derivative instruments and contracts to maintain the desired level of exposure arising from these risks. Our policy is to hedge our exposure to risks, when possible, within boundaries deemed appropriate by management.
A discussion of our accounting policies for derivative financial instruments is included in note 2 “Accounting Policies” of our consolidated financial statements included herein. Further information on our exposure to market risk is included in note 27 “Financial Instruments” of our consolidated financial statements included herein.
The following analysis provides quantitative information regarding our exposure to foreign currency exchange rate risk and interest rate risk. There are certain shortcomings inherent in the sensitivity analysis presented, primarily due to the assumption that exchange rates change in a parallel fashion and that interest rates change instantaneously.
Interest rate risk. A significant portion of our long-term debt obligation is subject to adverse movements in interest rates. Our interest rate risk management policy permits economic hedge relationships in order to reduce the risk associated with adverse fluctuations in interest rates. We use interest rate swaps and fixed rate debt to manage the exposure to adverse movements in interest rates. Interest rate swaps are used to convert floating rate debt obligations to a fixed rate in order to achieve an overall desired position of fixed and floating rate debt. Credit exposures are monitored on a counterparty basis, with all new transactions subject to senior management approval.
As of December 31, 2021, the notional amount of interest rate swaps outstanding in respect of our debt obligation was $505.0 million, representing approximately 50.3% of our floating rate loans. The principal of our floating rate loans outstanding as of December 31, 2021 was $1,004.9 million. Based on our floating rate debt at December 31, 2021, a one-percentage point increase in the floating interest rate would increase our interest expense by $4.0 million per annum. For disclosure of the fair value of the derivatives and debt obligations outstanding as of December 31, 2021, see note 27 “Financial Instruments” of our consolidated financial statements included herein.
Foreign currency risk. The majority of our transactions, assets and liabilities are denominated in U.S. Dollars, our functional currency. Periodically, we may be exposed to foreign currency exchange fluctuations as a result of expenses paid by certain subsidiaries in currencies other than U.S. Dollars, which includes British Pounds, or GBP, Norwegian Kroners, or NOK, and Euros, in relation to our administrative office in the UK, operating expenses and capital expenditure projects incurred in a variety of foreign currencies. Based on our GBP expenses for 2021, a 10% depreciation of the U.S. Dollar against GBP would have increased our expenses by $1.8 million.
We operate a branch in Norway, where the majority of expenses are incurred in NOK. Based on our NOK administrative expenses incurred in 2021, a 10% depreciation of the U.S. Dollar against NOK would have increased our expenses by $2.6 million.
The base currency of the majority of our seafaring officers' remuneration was the Euro. Based on the crew costs incurred in 2021, a 10% depreciation of the U.S. Dollar against the Euro would have increased our crew cost for 2021 by $2.9 million.
Commodity price risk. As of December 31, 2021, we have two derivative assets in relation to the LTA:
The Hilli oil derivative instrument represents the fair value of the estimated discounted cash flows of payments due as a result of the Brent Crude price moving above the contractual floor of $60.00 per barrel over the contract term. The derivative asset is adjusted to fair value at each balance date and, on December 31, 2021, the value of this asset is $127.5 million. Movements in the price of Brent Crude will cause the derivative asset, and resulting fair value movements, to fluctuate. However, we bear no downside risk should the Brent Crude price move below $60.00.
In 2021, we signed an agreement to increase the utilization of Hilli by 200,000 tons for 2022. The tolling fee for the 2022 incremental capacity is linked to European gas prices at the Dutch Title Transfer Facility (“TTF”). The Hilli gas derivative instrument represents the fair value of the estimated discounted cash flows of the additional payments due to us as a result of forecasted TTF prices and forecasted EUR/USD exchange rates, above a floor of $0.5652/MMBTU. The derivative asset is adjusted to fair value at each balance date and, on December 31, 2021, the value of this asset is $79.6 million. Movements in the TTF price will cause the derivative asset, and resulting fair value movements, to fluctuate. However, we bear no downside risk should the TTF price move below $0.5652/MMBTU.
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As of December 31, 2021, we were party to commodity swaps to manage our exposure to the European natural gas prices, the notional quantity of commodity swaps outstanding was 23,249 tons, and a 10% increase in TTF prices would result in a loss of $2.3 million per annum. For disclosure of the fair value of the derivatives and debt obligations outstanding as of December 31, 2021, see note 27 “Financial Instruments” of our consolidated financial statements included herein.
ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES
Not applicable.
ITEM 13. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES
None.
ITEM 14. MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS
None.
ITEM 15. CONTROLS AND PROCEDURE
(a) Disclosure Controls and Procedures
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Exchange Act reports is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
Under the supervision of our Company’s Chief Executive Officer and Chief Financial Officer, we carried out an evaluation of the effectiveness of our disclosure controls and procedures, pursuant to Rule 13a-15(b) and 15d-15(b) of the Exchange Act of 1934, as of December 31, 2021. At the time our Annual Report on Form 20-F for the year ended December 31, 2021 was filed on April 28, 2022, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2021.
(b) Management's annual report on internal controls over financial reporting
In accordance with the requirements of Rule 13a-15 of the Securities Exchange Act of 1934, as amended, the following report is provided by management in respect of our internal control over financial reporting. As defined in the Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended, internal control over financial reporting is a process designed by, or under the supervision of, our Chief Executive Officer and Chief Financial Officer, or persons performing similar functions, and effected by our Board of Directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of the consolidated financial statements for external purposes in accordance with U.S. GAAP and includes those policies and procedures that:
•pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect our transactions and dispositions of assets;
•provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with U.S. GAAP, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors of the Company; and
•provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.
Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Our internal control system was designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our published consolidated financial statements for external purposes under U.S. GAAP.
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In connection with the preparation of our annual consolidated financial statements, management has undertaken an assessment of the effectiveness of our internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013), issued by the Committee of Sponsoring Organizations of the Treadway Commission.
Management’s assessment included an evaluation of the design of our internal control over financial reporting and testing of the operational effectiveness of those controls. Based on this assessment, management has concluded and hereby reports that as of December 31, 2021, our internal control over financial reporting was effective.
The Company’s independent registered public accounting firm has issued an attestation report on the effectiveness of the Company’s internal control over financial reporting.
(c) Attestation report of the registered public accounting firm
The effectiveness of our internal control over financial reporting as of December 31, 2021 has been audited by Ernst & Young LLP, an independent registered public accounting firm, as stated in their report which appears on page F-3 of our consolidated financial statements.
(d) Changes in internal control over financial reporting
There were no changes in our internal control over financial reporting during the period covered by this Annual Report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 16A. AUDIT COMMITTEE FINANCIAL EXPERT
Our board of directors has determined that Lori Wheeler Naess and Daniel Rabun each qualify as an audit committee financial expert and are both independent, in accordance with SEC Rule 10a-3 pursuant to Section 10A of the Securities Exchange Act of 1934.
ITEM 16B. CODE OF ETHICS
We have adopted a Corporate Code of Business Ethics and Conduct that applies to all our employees. A copy of our Corporate Code of Business Ethics and Conduct may be found on our website www.golarlng.com. This website is provided as an inactive textual reference only. Information contained on our website does not constitute part of this annual report. We will provide any person, free of charge, a copy of our Code of Ethics upon written request to our registered office. Additionally, our Code of Business Ethics and Conduct is included as Exhibit 11.1 of this annual report. Any waivers that are granted from any provision of our Code of Business Ethics and Conduct may be disclosed on our website within five business days following the date of such waiver.
ITEM 16C. PRINCIPAL ACCOUNTANT FEES AND SERVICES
(a)Audit Fees
The following table sets forth, for the two most recent fiscal years, the aggregate fees billed for professional services rendered by the principal accountant, Ernst & Young LLP for the audit of our annual financial statements and services provided by the principal accountant in connection with statutory and regulatory filings or engagements for the two most recent fiscal years.

(in thousands of $) |
Fiscal year ended December 31, 2021 | $ | 1,962 |
Fiscal year ended December 31, 2020 | $ | 1,820 |

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(b) Audit-Related Fees
The following table sets forth, for the two most recent fiscal years, the aggregate fees billed for assurance and related services, not included under “(a) Audit Fees”, rendered by the principal accountant for the audit of our annual financial statements and services provided by the principal accountant in connection with statutory and regulatory filings or engagements for the two most recent fiscal years.

(in thousands of $) |
Fiscal year ended December 31, 2021 | $ | 148 |
Fiscal year ended December 31, 2020 | $ | 67 |

(c) Tax Fees
The following table sets forth, for the two most recent fiscal years, the aggregate fees billed for professional services rendered by the principal accountant for tax compliance, tax advice and tax planning.

(in thousands of $) |
Fiscal year ended December 31, 2021 | $ | 5 |
Fiscal year ended December 31, 2020 | $ | 4 |

(d) All Other Fees
The following table sets forth, for the two most recent fiscal years, the aggregate fees billed for professional services rendered by the principal accountant for other services that are not included in the scope of the current year audit or tax services as mentioned above. This majority of the balance comprises of advisory services provided during the year.

(in thousands of $) |
Fiscal year ended December 31, 2021 | $ | 72 |
Fiscal year ended December 31, 2020 | $ | 322 |

(e) Audit Committee's Pre-Approval Policies and Procedures
Our board of directors has adopted pre-approval policies and procedures in compliance with paragraph (c)(7)(i) of Rule 2-01 of Regulation S-X that require our board of directors to approve the appointment of our independent auditor before such auditor is engaged and to approve each of the audit and non-audit related services to be provided by such auditor. All services provided by the principal auditor in 2021 and 2020 were approved by our board of directors pursuant to the pre-approval policy.
ITEM 16D. EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES
Not applicable.
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ITEM 16E. PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS
In February 2021, our board of directors approved a share buyback program of up to $50 million of our common shares. During 2021, we repurchased an aggregate of 2.0 million shares for a cost of $24.5 million and subsequently cancelled all our treasury shares in September 2021.

| Total number of shares purchased |  | Average price paid per share |  | Total value of shares purchased as part of publicly announced plan or program |  | Maximum value of shares (in $) that may be purchased under the plan or program
April 2021 | 1,184,662 |  |  | $ | 11.55 |  |  | 13,711,335 |  |  | 36,288,665 |
June 2021 | 500,103 |  |  | $ | 13.54 |  |  | 6,783,883 |  |  | 29,504,782 |
July 2021 | 299,882 |  |  | $ | 13.28 |  |  | 3,988,446 |  |  | 25,516,336 |
March 2022 | 368,496 |  |  | $ | 17.80 |  |  | 6,565,840 |  |  | 18,950,496 |

ITEM 16F. CHANGE IN REGISTRANT'S CERTIFYING ACCOUNTANT
Not applicable.
ITEM 16G. CORPORATE GOVERNANCE
Pursuant to an exception under Nasdaq Rule 5615, or Nasdaq listing standards available to foreign private issuers, we are not required to comply with all of the corporate governance practices followed by U.S. companies under the Nasdaq's listing standards, which are available at www.nasdaq.com. As a foreign private issuer, we are permitted to follow our home country practices in lieu of certain Nasdaq corporate governance requirements. We have certified to Nasdaq that our corporate governance practices are in compliance with, and are not prohibited by, the laws of Bermuda.
We are exempt from many of the Nasdaq's corporate governance practices other than the requirements regarding the disclosure of a going concern audit opinion, submission of a listing agreement, notification of material non-compliance with Nasdaq's corporate governance practices and the establishment and composition of an audit committee and a formal written audit committee charter. The practices we follow in lieu of Nasdaq's corporate governance requirements are as follows:
Independence of directors. We are exempt from certain Nasdaq requirements regarding independence of directors. Consistent with Bermuda law, our board of directors is not required to be composed of a majority of independent directors. Currently, five of the seven members of the board of directors, Daniel Rabun, Lori Wheeler Naess, Carl Steen, Niels Stolt-Nielsen and Thorleif Egeli are independent according to Nasdaq's standards for independence. Our board of directors does not hold meetings at which only independent directors are present.
Audit Committee. We are exempt from certain Nasdaq requirements regarding our audit committee. Consistent with Bermuda law, the directors on our audit committee are not required to comply with certain of Nasdaq’s independence requirements for audit committee members, and our management is responsible for the proper and timely preparation of our annual reports, which are audited by independent auditors. However, the committee currently consists of three independent directors, Lori Wheeler Naess, Daniel Rabun and Carl Steen.
Compensation Committee. We are exempt from certain Nasdaq requirements regarding our compensation committee. Consistent with Bermuda law, our compensation committee may consist of members who are not independent directors. However, the committee currently consists of three independent directors, Carl Steen, Niels Stolt-Nielsen and Daniel Rabun. The primary responsibility of this committee is to review, approve and make recommendations to the board regarding compensation for directors and management.
Nomination Committee. We are exempt from certain Nasdaq requirements regarding our nomination committee. Consistent with Bermuda law, our nomination committee may consist of members who are not independent directors. However, the committee is currently comprised of two independent directors, Carl Steen and Daniel Rabun. The primary responsibility of this committee is to select and recommend to the board, director and committee member candidates.
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Share Issuance. In lieu of obtaining shareholder approval prior to the issuance of securities in certain circumstances, consistent with Bermuda law and our Bye-Laws, the board of directors approves share issuances.
As a foreign private issuer, we are not required to solicit proxies or provide proxy statements to Nasdaq pursuant to Nasdaq's corporate governance rules or Bermuda law. Consistent with Bermuda law, and as provided in our amended Bye-laws, we will notify our shareholders of shareholder meetings at least seven days before such meeting. This notification will contain, among other things, information regarding business to be transacted at the meeting.
We believe that our established corporate governance practices satisfy the Nasdaq listing standards.
ITEM 16H. MINE SAFETY DISCLOSURE
Not applicable.
ITEM 17. FINANCIAL STATEMENTS
See Item 18.
ITEM 18. FINANCIAL STATEMENTS
The following financial statements listed below and set forth on pages F-1 through to F-71 are filed as part of this Annual Report.
ITEM 19. EXHIBITS
The following exhibits are filed as part of this Annual Report:

Number | Description of Exhibit
1.1** | Memorandum of Association of Golar LNG Limited as adopted on May 9, 2001, incorporated by reference to Exhibit 1.1 of Golar LNG Limited’s Registration Statement on Form 20-F, filed with the SEC on November 27, 2002, File No. 00050113, or the Original Registration Statement.
1.2** | Bye-Laws of Golar LNG Limited amended and adopted September 20, 2013, incorporated by reference to Exhibit 3.1 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on July 1, 2014.
1.3** | Bye-Laws of Golar LNG Limited amended and adopted September 24, 2020, incorporated by reference to Exhibit 4.1 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on November 30, 2020.
1.4** | Certificate of Incorporation as adopted on May 10, 2001, incorporated by reference to Exhibit 1.3 of Golar LNG Limited’s Original Registration Statement.
1.5** | Certificate of deposit of memorandum of increase of share capital of Golar LNG Limited registered on June 20, 2001 (increasing Golar LNG Limited’s authorized capital), incorporated by reference to Exhibit 1.4 of Golar LNG Limited’s Original Registration Statement.
1.6** | Certificate of deposit of memorandum of increase of share capital of Golar LNG Limited registered November 6, 2014, incorporated by reference to Exhibit 1.6 of Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2014.

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Number | Description of Exhibit
2.1** | Form of share certificate incorporated by reference to Exhibit 2.1 of Golar LNG Limited’s Annual Report on Form 20-F for the fiscal year ended December 31, 2010.
2.2** | Indenture, dated February 17, 2017, between Golar LNG Limited and Deutsche Bank Trust Company Americas as a Bond Trustee, incorporated by reference to Exhibit 2.2 of Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2016.
2.3* | Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934.
4.1** | Rules of the Bermuda Employee Share Option Scheme, incorporated by reference to Exhibit 4.6 of Golar LNG Limited’s Original Registration Statement.
4.2** | Bermuda Tax Assurance, dated May 23, 2011, incorporated by reference to Exhibit 4.4 of Golar LNG Limited’s Annual Report on Form 20-F for the fiscal year ended December 31, 2013.
4.3** | Memorandum of Agreement, dated September 9, 2015, by and between Golar Hilli Corporation and Fortune Lianjiang Shipping S.A., providing for, among other things, the sale and leaseback of the Hilli, incorporated by reference to Exhibit 4.21 of Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2015.
4.4** | Bareboat charter by and between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A., dated September 9, 2015, incorporated by reference to Exhibit 4.2 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on August 31, 2018.
4.5** | Additional Clauses to the Bareboat Charter Party dated September 9, 2015 between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A., incorporated by reference to Exhibit 4.3 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on August 31, 2018.
4.6** | Common Terms Agreements, by and between Golar Hilli Corp. and Fortune Lianjiang Shipping S.A., dated September 9, 2015, incorporated by reference to Exhibit 4.4 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on August 31, 2018.
4.7** | Purchase and Sale Agreement, dated August 15, 2017, by and among Golar LNG Limited, KS Investments Pte. Ltd., Black & Veatch International Company and Golar Partners Operating LLC, incorporated by reference to Exhibit 4.1 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on September 29, 2017.
4.8** | 2017 long-term incentive plan, incorporated by reference to Exhibit 4.6 to Golar LNG Limited's Registration statement on form S-8, filed on November 20, 2017.
4.9**/+ | Liquefaction Tolling Agreement, dated November 29, 2017, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU, incorporated by reference to Exhibit 4.29 of Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2017.
4.10*/++ | First Amendment to Liquefaction Tolling Agreement, dated November 15, 2019, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.

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Number | Description of Exhibit
4.11*/++ | Second Amendment to Liquefaction Tolling Agreement, dated March 23, 2021, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
4.12*/++ | Third Amendment to Liquefaction Tolling Agreement, dated July 22, 2021, between Société Nationale des Hydrocarbures, Perenco Cameroon SA, Golar Hilli Corporation and Golar Cameroon SASU.
4.13** | Amendment Agreement, dated March 23 2018, relating to the Purchase and Sale Agreement by and between Golar LNG Partners LP, Golar LNG Limited, KS Investments Pte. Ltd. and Black & Veatch International Company, incorporated by reference to Exhibit 4.1 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on July 30, 2018.
4.14** | Amended and Restated Limited Liability Company Agreement of Golar Hilli LLC, dated July 12, 2018, incorporated by reference to Exhibit 4.1 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on August 31, 2018.
4.15** | Amended and Restated Limited Liability Company Agreement of Golar Hilli LLC dated as of April 15, 2021, by and among Golar LNG Limited, Golar Partners Operating LLC, KSI Investments Pte. Ltd. and Black & Veatch International Corporation, incorporat ed by refere nce to Exhibit 4.14 to Golar LNG Limit ed Annual Report on Form 20-F for the fiscal year ended December 31, 20 20.
4.16** | Golar LNG Partners LP Guarantee Agreement, dated as of July 12, 2018, incorporated by reference to Exhibit 4.5 to Golar LNG Limited’s Report of Foreign Issuer on Form 6-K filed on August 31, 2018.
4.17**/+ | Lease and Operate Agreement by and between Gimi MS Corporation and BP Mauritania Investments Limited, dated February 26, 2019, incorporated by reference to Exhibit 4.26 to Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2018.
4.18**/++ | $700 million facility agreement dated October 24, 2019, by and between Gimi MS Corporation, ABN Amro Bank N.V., Clifford Capital Pte. Ltd., ING Bank N.V. and Natixis, incorporated by reference to Exhibit 1.1 to Golar LNG Limited's Report of Foreign Issues on Form 6-K filed on November 30, 2020.
4.19**/++ | First supplemental agreement to $700 million facility dated January 19, 2021, by and among Gimi MS Corporation, Golar LNG Limited, Gimi Holding Company Limited and ING Bank N.V., incorporated by reference to Exhibit 4.18 to Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2020.
4.20*/++ | Second supplemental agreement to $700 million facility agreement dated March 2, 2021, by and between Gimi MS Corporation, ABN Amro Bank N.V., Clifford Capital Pte. Ltd., ING Bank N.V. and Natixis.
4.21** | Agreement and plan of Merger dated January 13, 2021, relating to the sale of Golar LNG Partners LP, by and between Golar GP LLC, New Fortress Energy Inc, Lobos Acquisition LLC and NFE International Holdings Limited, incorporated by reference to Exhibit 4.1 to Golar LNG Limited's Report of Foreign Issues on Form 6-K filed on January 19, 2021.
4.22** | Transfer Agreement dated January 13, 2021, relating to the sale of Golar LNG Partners LP, by and between Golar LNG Limited, Golar GP LLC and NFE International Holdings Limited, incorporated by reference to Exhibit 4.2 to Golar LNG Limited's Report of Foreign Issues on Form 6-K filed on January 19, 2021.
4.23** | Support Agreement dated January 13, 2021, relating to the sale of Golar LNG Partners LP, by and between Golar LNG Limited, Golar GP LLC and NFE International Holdings Limited, incorporated by reference to Exhibit 4.3 to Golar LNG Limited's Report of Foreign Issues on Form 6-K filed on January 19, 2021.

77

Number | Description of Exhibit
4.24** | Agreement and plan of Merger dated January 13, 2021, relating to the sale of Hygo Energy Transition LTD, between New Fortress Energy Inc, Golar LNG Limited, Stonepeak Infrastructure Fund II Cayman (G) LTD and Lobos Acquisition LLC, incorporated by reference to Exhibit 4.4 to Golar LNG Limited's Report of Foreign Issues on Form 6-K filed on January 19, 2021.
4.25** | Omnibus Agreement dated as of April 15, 2021, by and among Golar LNG Limited, certain direct and indirect subsidiaries of Golar LNG Limited and New Fortress Energy, Inc, incorporated by reference to Exhibit 4.23 to Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2020.
4.26** | Omnibus Agreement (Hygo) dated as of April 15, 2021 by and among Golar LNG Limited, certain direct and indirect subsidiaries of Golar LNG Limited party thereto and New Fortress Energy Inc, incorporated by reference to Exhibit 4.24 to Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2020.
4.27** | Shareholders’ Agreement dated as of April 15, 2021 by and among New Fortress Energy Inc., Golar LNG Limited and Stonepeak Infrastructure Fund II Cayman (G) Ltd, incorporated by reference to Exhibit 4.25 to Golar LNG Limited Annual Report on Form 20-F for the fiscal year ended December 31, 2020.
4.28* | $300 million unsecured No r wegian Bond dated March 10, 2012, by and between Golar LNG Limited, DNB Bank ASA, Danske Bank A/S, Pareto Secur ities AS and Nordea Bank Abp.
4.29*/++ | Share purchase agreement dated dated January 26, 2022 by and between Cool Company Ltd and Golar LNG Limited.
4.30*/++ | Amendment agreement to share purchase agreement dated February 25, 2022 by and between Cool Company Ltd and Golar LNG Limited.
8.1* | Golar LNG Limited subsidiaries.
11.1** | Golar LNG Limited Corporate Code of Business Ethics and Conduct, incorporated by reference to Exhibit 14.1 of Golar LNG Limited’s Annual Report on Form 20-F for the year ended December 31, 2003.
12.1* | Certification of the Principal Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
12.2* | Certification of the Principal Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
13.1* | Certification under Section 906 of the Sarbanes-Oxley act of 2002 of the Principal Executive Officer.
13.2* | Certification under Section 906 of the Sarbanes-Oxley act of 2002 of the Principal Financial Officer.

78

Number | Description of Exhibit
15.1* | Consent of Independent Registered Public Accounting Firm - Ernst & Young LLP.

_________________________
* Filed herewith.
** Incorporated by reference.
+ Certain portions have been omitted pursuant to a confidential treatment request. Omitted information have been separately filed with the Securities and Exchange Commission.
++ Certain portions have been omitted.
101. INS* XBRL Instance Document
101. SCH* XBRL Taxonomy Extension Schema
101. CAL* XBRL Taxonomy Extension Schema Calculation Linkbase
101. DEF* XBRL Taxonomy Extension Schema Definition Linkbase
101. LAB* XBRL Taxonomy Extension Schema Label Linkbase
101. PRE* XBRL Taxonomy Extension Schema Presentation Linkbase
79

SIGNATURES
The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.

| Golar LNG Limited
| (Registrant)
Date | April 28, 2022 | By | /s/ Eduardo Maranhão
|  | Eduardo Maranhão
|  | Principal Financial Officer

80

GOLAR LNG LIMITED
INDEX TO AUDITED CONSOLIDATED FINANCIAL STATEMENTS

| Page
REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM (PCAOB ID 1438) | F-2
CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019 | F-5
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019 | F-6
CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2021 AND 2020 | F-7
CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019 | F-8
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019 | F-10
NOTES TO THE AUDITED CONSOLIDATED FINANCIAL STATEMENTS | F-11

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and the Board of Directors of Golar LNG Limited
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of Golar LNG Limited (the “Company”) as of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income/(loss), cash flows and changes in equity for each of the three years in the period ended December 31, 2021 and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated April 28, 2022, expressed an unqualified opinion thereon.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
F-2

Vessel impairment
Description of the matter |  | The Company’s vessels balance was $2,878 million as of December 31, 2021. As explained in Note 2 to the consolidated financial statements, management performs an annual impairment assessment at the year-end and whenever events or changes in circumstances indicate that the carrying value of a vessel might exceed its fair value. If indicators of impairment are identified, management analyzes the future cash flows expected to be generated throughout the remaining useful life of vessels where indicators of impairment exist. These undiscounted cash flows are estimated using certain assumptions, such as forecasts in respect of charter rates combined with vessel utilization rates. In relation to forecasted charter rates, the Company applies the currently contracted charter rate for the periods in the forecasted cash flow where the vessel is on charter. For vessels with no contracted charters or when a vessel’s forecasted cash flow period falls beyond the contracted charter, the forecasted charter rates are estimated based on industry analysis and broker reports (‘charter rates post-contract expiry’). Auditing the Company’s impairment assessment was complex due to the significant estimation uncertainty, subjectivity, and judgment in forecasting the undiscounted cash flows of the vessels. The significant assumptions that drive the forecasted cash flows used in management’s analysis are the estimation of charter rates post-contract expiry combined with vessel utilization. These significant assumptions are forward looking and subject to future economic and market conditions.
How we addressed the matter in our audit |  | We obtained an understanding of the Company’s impairment process and evaluated the design and tested the operating effectiveness of the controls over the Company’s determination of the key inputs to the impairment assessment, as described above. This included evaluating management’s review of the identified impairment indicators and determination of the assumptions used in the undiscounted cash flows to be generated throughout the remaining useful life of the vessels. We analyzed management’s impairment assessment by comparing the methodology used to assess impairment of each vessel against the accounting guidance in ASC 360 – Property, Plant and Equipment (“ASC 360”). We tested the reasonableness of the estimated charter revenues by comparing the related inputs (primarily charter rates post-contract expiry combined with vessel utilization) to forecasted market rates and historical information. We evaluated whether the gradual step up and step down of charter rates estimated by management is comparable to the liquefied natural gas (‘LNG’) curves published in the market and whether the calculations reflect the expected utilization of the vessels. We also inspected market reports and analyzed how the economic factors such as future demand and supply for LNG carriers and floating storage regasification units (‘FSRUs’) have been incorporated in management’s estimates of future charter revenues. Further, we calculated the average charter post-contract expiry rate used across the remaining useful life of the vessels and compared it to the historical average across a similar period. We identified vessels which are not employed under active charters or are nearing the end of their charter and considered them to be highly sensitive to the charter rate. In relation to these vessels, we independently calculated the charter rate at which the undiscounted cash flows equalled the carrying value of the vessel (‘break-even charter rate’) and compared the rates against forecasted market rates. Further, we calculated the minimum utilization percentages required for these vessels by analyzing the break-even charter rates relative to the forecasted market rates, and assessed these percentages by comparing against historical utilization averages together with the LNG market outlook for a similar type of vessel. We also compared the assumptions and estimates made by management in their impairment assessment for the prior year against the actual results in 2021 to assess the precision of management’s forecasting process. In addition, we assessed the adequacy of the related disclosures in the financial statements.

/s/ Ernst & Young LLP |
We have served as the Company’s auditor since 2014. |
London, United Kingdom |
April 28, 2022 |

F-3

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of Golar LNG Limited
Opinion on Internal Control over Financial Reporting
We have audited Golar LNG Limited’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, Golar LNG Limited (the “Company”) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the 2021 consolidated financial statements of the Company and our report dated April 28, 2022 expressed an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.
Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Ernst & Young LLP |
London, United Kingdom |
April 28, 2022 |

F-4

GOLAR LNG LIMITED
CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019

(in thousands of $, except per share amounts) | Notes |  | 2021 |  | 2020 |  | 2019
Time and voyage charter revenues | 13 |  | 202,968 |  |  | 191,881 |  |  | 185,407 |
Time charter revenues - collaborative arrangement | 13 |  | — |  |  | — |  |  | 23,359 |
Liquefaction services revenue | 7 |  | 221,020 |  |  | 226,061 |  |  | 218,096 |
Vessel and other management fees | 7, 14, 28 |  | 27,777 |  |  | 20,695 |  |  | 21,888 |
Total operating revenues |  |  | 451,765 |  |  | 438,637 |  |  | 448,750 |
Vessel operating expenses |  |  | (120,325) |  |  | (108,926) |  |  | (121,290) |
Voyage, charterhire and commission expenses, net | 28 |  | (10,774) |  |  | (12,634) |  |  | (19,908) |
Voyage, charterhire and commission expenses - collaborative arrangement | 28 |  | — |  |  | — |  |  | (18,933) |
Administrative expenses |  |  | (35,021) |  |  | (35,311) |  |  | (52,171) |
Project development expenses |  |  | (2,787) |  |  | (8,891) |  |  | (4,990) |
Depreciation and amortization | 19 |  | (105,952) |  |  | (107,923) |  |  | (113,033) |
Impairment of long-term assets | 6 |  | — |  |  | — |  |  | (42,098) |
Total operating expenses |  |  | (274,859) |  |  | (273,685) |  |  | (372,423) |
Other operating income |  |  |  |  |  |  |
Realized and unrealized gain/(loss) on oil and gas derivative instruments | 8 |  | 204,663 |  |  | (42,561) |  |  | (26,001) |
Other operating income | 28, 29 |  | 5,020 |  |  | 3,262 |  |  | 10,333 |
Operating income |  |  | 386,589 |  |  | 125,653 |  |  | 60,659 |
Other non-operating (losses)/income | 9 |  | (361,928) |  |  | 5,682 |  |  | — |
Financial income/(expense) |  |  |  |  |  |  |
Interest income | 28 |  | 139 |  |  | 1,572 |  |  | 10,479 |
Interest expense |  |  | (55,163) |  |  | (69,354) |  |  | (103,124) |
Gains/(losses) on derivative instruments | 10 |  | 24,348 |  |  | (52,423) |  |  | (38,044) |
Other financial items, net | 10 |  | (759) |  |  | (1,552) |  |  | (5,522) |
Net financial expense |  |  | (31,435) |  |  | (121,757) |  |  | (136,211) |
(Loss)/income before taxes and net income/(losses) from equity method investments |  |  | (6,774) |  |  | 9,578 |  |  | (75,552) |
Income taxes | 11 |  | (1,740) |  |  | (981) |  |  | (1,024) |
Income/(losses) from equity method investments | 2, 17 |  | 1,080 |  |  | (538) |  |  | (2,515) |
Net (loss)/income from continuing operations |  |  | (7,434) |  |  | 8,059 |  |  | (79,091) |
Net income/(loss) from discontinued operations | 14 |  | 568,049 |  |  | (175,989) |  |  | (43,284) |
Net income/(loss) |  |  | 560,615 |  |  | (167,930) |  |  | (122,375) |
Net income attributable to non-controlling interests |  |  | (146,764) |  |  | (105,627) |  |  | (89,581) |
Net income/(loss) attributable to stockholders of Golar LNG Limited |  |  | 413,851 |  |  | (273,557) |  |  | (211,956) |
Earnings/(loss) per share attributable to Golar LNG Ltd stockholders Per common share amounts: |  |  |  |  |  |
Basic and dilutive loss per share from continuing operations | 12 |  | $ | (1.43) |  |  | $ | (1.01) |  |  | $ | (1.68) |
Basic and dilutive earnings/(loss) per share from discontinued operations | 12 |  | $ | 5.25 |  |  | $ | (1.81) |  |  | $ | (0.43) |
Cash dividends paid per share |  | $ | — |  |  | $ | — |  |  | $ | 0.45 |

The accompanying notes are an integral part of these consolidated financial statements.
F-5

GOLAR LNG LIMITED
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME/(LOSS) FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019
(in thousands of $)

| Notes |  | 2021 |  | 2020 |  | 2019
COMPREHENSIVE INCOME/(LOSS) |  |  |  |  |  |  |
Net income/(loss) |  |  | 560,615 |  |  | (167,930) |  |  | (122,375) |
Other comprehensive income/(loss): |  |  |  |  |  |  |
Gain/(loss) associated with pensions | 25 |  | 5,006 |  |  | (3,527) |  |  | (3,058) |
Share of equity method investment's comprehensive losses from discontinued operations (1) |  |  | (3,147) |  |  | (17,680) |  |  | (3,296) |
Realized accumulated comprehensive losses on disposal of equity method investment | 14 |  | 43,380 |  |  | — |  |  | — |
|  |  | 45,239 |  |  | (21,207) |  |  | (6,354) |
Comprehensive income/(loss) |  |  | 605,854 |  |  | (189,137) |  |  | (128,729) |
Comprehensive income/(loss) attributable to: |  |  |  |  |  |  |
Stockholders of Golar LNG Limited |  |  | 459,090 |  |  | (294,764) |  |  | (218,310) |
Non-controlling interests |  |  | 146,764 |  |  | 105,627 |  |  | 89,581 |
Comprehensive income/(loss) |  |  | 605,854 |  |  | (189,137) |  |  | (128,729) |

(1) No tax impact for the years ended December 31, 2021, 2020 and 2019.
The accompanying notes are an integral part of these consolidated financial statements.
F-6

GOLAR LNG LIMITED
CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2021 AND 2020
(in thousands of $, except share amounts)

| Notes |  | 2021 |  | 2020
ASSETS |  |  |  |  |
Current assets |  |  |  |  |
Cash and cash equivalents |  |  | 268,627 |  |  | 127,691 |
Restricted cash and short-term deposits | 15 |  | 77,337 |  |  | 100,361 |
Trade accounts receivable |  |  | 29,749 |  |  | 29,648 |
Amounts due from related parties | 28 |  | 3,484 |  |  | 2,112 |
Inventories |  |  | 536 |  |  | 1,533 |
Assets held for sale | 2 |  | — |  |  | 267,766 |
Other current assets | 16 |  | 545,864 |  |  | 8,682 |
Total current assets |  |  | 925,597 |  |  | 537,793 |
Non-current assets |  |  |  |  |
Restricted cash | 15 |  | 72,828 |  |  | 62,820 |
Equity method investments | 2, 17 |  | 52,215 |  |  | 44,385 |
Asset under development | 18 |  | 877,838 |  |  | 658,247 |
Vessels and equipment, net | 19 |  | 2,877,674 |  |  | 2,983,073 |
Other non-current assets | 20 |  | 142,143 |  |  | 27,911 |
Total assets |  |  | 4,948,295 |  |  | 4,314,229 |
LIABILITIES AND EQUITY |  |  |  |  |
Current liabilities |  |  |  |  |
Current portion of long-term debt and short-term debt | 21 |  | (1,051,582) |  |  | (982,845) |
Trade accounts payable |  |  | (12,405) |  |  | (10,579) |
Accrued expenses | 22 |  | (92,855) |  |  | (89,357) |
Other current liabilities | 23 |  | (150,380) |  |  | (85,419) |
Amounts due to related parties | 28 |  | — |  |  | (12,006) |
Total current liabilities |  |  | (1,307,222) |  |  | (1,180,206) |
Non-current liabilities |  |  |  |  |
Long-term debt | 21 |  | (1,358,219) |  |  | (1,367,937) |
Other non-current liabilities | 24 |  | (104,937) |  |  | (135,439) |
Total liabilities |  |  | (2,770,378) |  |  | (2,683,582) |
Commitments and contingencies EQUITY | 29 |  |  |  |
Share capital 108,222,604 common shares of $1.00 each issued and outstanding (2019: 109,943,594) | 26 |  | (108,223) |  |  | (109,944) |
Additional paid-in capital |  |  | (1,972,859) |  |  | (1,969,602) |
Contributed surplus |  |  | (200,000) |  |  | (200,000) |
Accumulated other comprehensive loss |  |  | 10,834 |  |  | 56,073 |
Retained losses |  |  | 539,598 |  |  | 930,950 |
Total stockholders' equity |  |  | (1,730,650) |  |  | (1,292,523) |
Non-controlling interests | 5 |  | (447,267) |  |  | (338,124) |
Total equity |  |  | (2,177,917) |  |  | (1,630,647) |
Total liabilities and equity |  |  | (4,948,295) |  |  | (4,314,229) |

The accompanying notes are an integral part of these consolidated financial statements.
F-7

GOLAR LNG LIMITED
CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019
(in thousands of $)

| Notes |  | 2021 |  | 2020 |  | 2019
Operating activities |  |  |  |  |  |  |
Net income/(loss) |  |  | 560,615 |  |  | (167,930) |  |  | (122,375) |
Adjustments to reconcile net income/(loss) to net cash provided by operating activities: |  |  |  |  |  |  |
Depreciation and amortization | 19 |  | 105,952 |  |  | 107,923 |  |  | 113,033 |
Gain on disposal of long lived asset | 18 |  | — |  |  | (5,682) |  |  | — |
Deconsolidation of lessor VIE | 5 |  | — |  |  | (4,809) |  |  | — |
Impairment of non-current assets | 6 |  | — |  |  | — |  |  | 7,347 |
Impairment of long-lived assets | 6 |  | — |  |  | — |  |  | 34,751 |
Amortization of deferred charges and debt guarantees, net |  |  | 3,049 |  |  | 3,890 |  |  | 6,527 |
Net (income)/losses from equity method investments | 2, 17 |  | (1,080) |  |  | 538 |  |  | 2,515 |
Net (income)/loss from discontinued operations | 2, 14 |  | (568,049) |  |  | 175,989 |  |  | 43,284 |
Dividend received from discontinued operations | 2 |  | — |  |  | — |  |  | 7,609 |
Drydocking expenditure |  |  | (1,591) |  |  | (10,622) |  |  | (24,881) |
Compensation cost related to employee stock awards |  |  | 3,520 |  |  | 5,421 |  |  | 8,882 |
Net foreign exchange losses |  |  | 466 |  |  | 3,221 |  |  | 1,241 |
Change in fair value of investment in listed equity securities | 27 |  | 295,776 |  |  | — |  |  | — |
Change in fair value of derivative instruments | 10 |  | (27,016) |  |  | 46,208 |  |  | 44,395 |
Change in fair value of oil and gas derivative instruments | 8 |  | (179,891) |  |  | 45,100 |  |  | 39,090 |
Change in assets and liabilities: |  |  |  |  |  |  |
Trade accounts receivable |  |  | (1,247) |  |  | (4,178) |  |  | 39,448 |
Inventories |  |  | 998 |  |  | (305) |  |  | 5,778 |
Other current and non-current assets |  |  | 979 |  |  | (15,822) |  |  | (5,868) |
Amounts due to/from related companies |  |  | (9,419) |  |  | 11,632 |  |  | 2,354 |
Trade accounts payable |  |  | 857 |  |  | 3,832 |  |  | (678) |
Accrued expenses |  |  | 6,192 |  |  | 3,769 |  |  | (39,683) |
Other current and non-current liabilities (1) |  |  | 63,770 |  |  | (52,392) |  |  | (56,224) |
Net cash provided by continuing operating activities |  |  | 253,881 |  |  | 145,783 |  |  | 106,545 |
Investing activities |  |  |  |  |  |  |
Additions to vessels and equipment |  |  | (925) |  |  | (3,880) |  |  | (24,389) |
Additions to asset under development |  |  | (213,481) |  |  | (298,304) |  |  | (376,276) |
Additions to equity method investments | 2 |  | (8,625) |  |  | (10,230) |  |  | (1,264) |
Dividends received from listed equity securities |  |  | 5,029 |  |  | — |  |  | — |
Proceeds from subscription of equity interest in Gimi MS Corporation | 5 |  | 25,403 |  |  | 11,081 |  |  | 115,246 |
Proceeds from disposal of long-lived assets | 18 |  | — |  |  | 190,131 |  |  | 3,160 |
Short-term loan advanced to related parties | 28 |  | (1,750) |  |  | — |  |  | — |
Net cash used in continuing investing activities |  |  | (194,349) |  |  | (111,202) |  |  | (283,523) |
Additions to equity method investments |  |  | — |  |  | (2,410) |  |  | (19,730) |
Dividends received |  |  | 460 |  |  | 10,584 |  |  | 29,207 |
Net proceeds from disposals of equity method investments |  |  | 119,535 |  |  | — |  |  | — |
Short-term loan advanced to related parties |  |  | — |  |  | (45,000) |  |  | — |
Proceeds from repayment of short-term loan advanced to related parties |  |  | — |  |  | 45,000 |  |  | — |
Proceeds from disposals to Golar Partners, net of cash disposed |  |  | — |  |  | — |  |  | 9,652 |
Net cash provided by discontinued investing activities | 2 |  | 119,995 |  |  | 8,174 |  |  | 19,129 |

F-8

| Notes |  | 2021 |  | 2020 |  | 2019
Financing activities |  |  |  |  |  |  |
Proceeds from short-term and long-term debt |  |  | 580,268 |  |  | 729,707 |  |  | 524,278 |
Repayments of short-term and long-term debt |  |  | (557,255) |  |  | (934,534) |  |  | (552,195) |
Net proceeds from the issuance of equity |  |  | — |  |  | 99,831 |  |  | — |
Cash dividends paid |  |  | (33,136) |  |  | (26,072) |  |  | (65,004) |
Financing costs paid |  |  | (17,000) |  |  | (14,577) |  |  | (24,464) |
Purchase of treasury shares | 26 |  | (24,484) |  |  | (16,650) |  |  | (18,615) |
Net cash used in financing activities |  |  | (51,607) |  |  | (162,295) |  |  | (136,000) |
Net increase/(decrease) in cash, cash equivalents and restricted cash |  |  | 127,920 |  |  | (119,540) |  |  | (293,849) |
Cash, cash equivalents and restricted cash at beginning of period |  |  | 290,872 |  |  | 410,412 |  |  | 704,261 |
Cash, cash equivalents and restricted cash at end of period |  |  | 418,792 |  |  | 290,872 |  |  | 410,412 |
Supplemental disclosure of cash flow information: |  |  |  |  |  |  |
Cash paid during the year for: |  |  |  |  |  |  |
Interest paid, net of capitalized interest |  |  | 35,887 |  |  | 56,267 |  |  | 148,072 |
Income taxes paid |  |  | 694 |  |  | 1,181 |  |  | 663 |

(1) Includes accretion of discount on convertible bonds of $15.9 million, $15.6 million and $14.5 million for the years ended December 31, 2021, 2020 and 2019, respectively.
Supplemental note to the consolidated statements of cash flows
The following table identifies the balance sheet line-items included in cash, cash equivalents and restricted cash presented in the consolidated statements of cash flows:

(in thousands of $) | Notes | 2021 | 2020 | 2019 | 2018
Cash and cash equivalents |  | 268,627 |  | 127,691 |  | 222,123 |  | 217,835 |
Restricted cash and short-term deposits (current portion) | 15 | 77,337 |  | 100,361 |  | 111,545 |  | 332,033 |
Restricted cash (non-current portion) | 15 | 72,828 |  | 62,820 |  | 76,744 |  | 154,393 |
|  | 418,792 |  | 290,872 |  | 410,412 |  | 704,261 |

F-9

GOLAR LNG LIMITED
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019
(in thousands of $)

| Notes |  | Share Capital |  | Treasury Shares |  | Additional Paid-in Capital |  | Contributed Surplus |  | Accumulated Other Comprehensive Loss (1) |  | Retained (Losses)/Earnings |  | Non-controlling Interests |  | Total Equity
Balance at December 31, 2018 |  |  | 101,303 |  |  | (20,483) |  |  | 1,857,196 |  |  | 200,000 |  |  | (28,512) |  |  | (364,379) |  |  | 80,666 |  |  | 1,825,791 |
Net (loss)/income |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (211,956) |  |  | 89,581 |  |  | (122,375) |
Dividends |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (28,810) |  |  | (22,939) |  |  | (51,749) |
Employee stock compensation |  |  | — |  |  | — |  |  | 9,371 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 9,371 |
Forfeiture of employee stock compensation |  |  | — |  |  | — |  |  | (489) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (489) |
Sale of equity interest and proceeds from subscription of equity interest in Gimi MS Corporation | 5 |  | — |  |  | — |  |  | 9,989 |  |  | — |  |  | — |  |  | — |  |  | 105,257 |  |  | 115,246 |
Treasury shares | 27, 28 |  | — |  |  | (18,615) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (18,615) |
Other comprehensive loss |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (6,354) |  |  | — |  |  | — |  |  | (6,354) |
Balance at December 31, 2019 |  |  | 101,303 |  |  | (39,098) |  |  | 1,876,067 |  |  | 200,000 |  |  | (34,866) |  |  | (605,145) |  |  | 252,565 |  |  | 1,750,826 |
Net (loss)/income |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (273,557) |  |  | 105,627 |  |  | (167,930) |
Dividends |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (26,340) |  |  | (26,340) |
Employee stock compensation |  |  | — |  |  | — |  |  | 5,671 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 5,671 |
Forfeiture of employee stock compensation |  |  | — |  |  | — |  |  | (250) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (250) |
Restricted stock units |  |  | 73 |  |  | — |  |  | (73) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Proceeds from subscription of equity interest in Gimi MS Corporation | 5 |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 11,081 |  |  | 11,081 |
Repurchase and cancellation of treasury shares | 27, 28 |  | (3,500) |  |  | 39,098 |  |  | — |  |  | — |  |  | — |  |  | (52,248) |  |  | — |  |  | (16,650) |
Net proceeds from issuance of shares | 27 |  | 12,068 |  |  | — |  |  | 88,187 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 100,255 |
Deconsolidation of lessor VIE | 5 |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (4,809) |  |  | (4,809) |
Other comprehensive loss |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (21,207) |  |  | — |  |  | — |  |  | (21,207) |
Balance at December 31, 2020 |  |  | 109,944 |  |  | — |  |  | 1,969,602 |  |  | 200,000 |  |  | (56,073) |  |  | (930,950) |  |  | 338,124 |  |  | 1,630,647 |
Net income/(loss) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 413,851 |  |  | 146,764 |  |  | 560,615 |
Dividends |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (37,136) |  |  | (37,136) |
Employee stock compensation |  |  | — |  |  | — |  |  | 4,330 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 4,330 |
Forfeiture of employee stock compensation |  |  | — |  |  | — |  |  | (809) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (809) |
Restricted stock units |  |  | 264 |  |  | — |  |  | (264) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Proceeds from subscription of equity interest in Gimi MS Corporation | 5 |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 25,403 |  |  | 25,403 |
Repurchase and cancellation of treasury shares | 27, 28 |  | (1,985) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (22,499) |  |  | — |  |  | (24,484) |
Realized accumulated comprehensive losses on disposal of equity method investment | 15 |  | — |  |  | — |  |  | — |  |  | — |  |  | 43,380 |  |  | — |  |  | — |  |  | 43,380 |
Deconsolidation of lessor VIE | 5 |  | — |  |  | — |  |  | — |  |  | — |  |  |  |  | — |  |  | (25,888) |  |  | (25,888) |
Other comprehensive loss |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1,859 |  |  | — |  |  | — |  |  | 1,859 |
Balance at December 31, 2021 |  |  | 108,223 |  |  | — |  |  | 1,972,859 |  |  | 200,000 |  |  | (10,834) |  |  | (539,598) |  |  | 447,267 |  |  | 2,177,917 |

(1) As at December 31, 2021, 2020 and 2019, our accumulated other comprehensive loss consisted of $5.0 million gain, $3.5 million loss and $3.1 million loss in relation to our pension and post retirement benefit plan and $3.1 million, $17.7 million and $3.3 million share of equity method investment's comprehensive loss from discontinued operations, respectively.
The accompanying notes are an integral part of these consolidated financial statements.
F-10

GOLAR LNG LIMITED
NOTES TO THE AUDITED CONSOLIDATED FINANCIAL STATEMENTS

1. | GENERAL

Golar LNG Limited (the “Company” or “Golar”) was incorporated in Hamilton, Bermuda on May 10, 2001 for the purpose of acquiring the liquefied natural gas (“LNG”) shipping interests of Osprey Maritime Limited, which was owned by World Shipholding Limited.
As of December 31, 2021, our fleet was comprised of nine LNG carriers, one Floating Storage Regasification Unit (“FSRU”) and three Floating Liquefaction Natural Gas vessels (“FLNGs”) (including one vessel under conversion to a FLNG and one vessel earmarked for conversion to a FLNG). We also operate vessels on behalf of third parties under management agreements.
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.

2. | BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES

Basis of preparation
These consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”).
The accounting policies set out below have been applied consistently to all periods in these consolidated financial statements.
Principles of consolidation
A variable interest entity (“VIE”) is defined by the accounting standard as a legal entity where either (a) equity interest holders as a group lack the characteristics of a controlling financial interest, including decision making ability and an interest in the entity's residual risks and rewards, or (b) the equity holders have not provided sufficient equity investment to permit the entity to finance its activities without additional subordinated financial support, or (c) the voting rights of some investors are not proportional to their obligations to absorb the expected losses of the entity, their rights to receive the expected residual returns of the entity, or both and substantially all of the entity's activities either involve or are conducted on behalf of an investor that has disproportionately few voting rights. A party that is a variable interest holder is required to consolidate a VIE if the holder has both (a) the power to direct the activities that most significantly impact the entity's economic performance and (b) the obligation to absorb losses that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE.
The accompanying consolidated financial statements include the financial statements of the entities listed in notes 4 and 5.
Investments in entities in which we directly or indirectly hold more than 50% of the voting control are consolidated in the financial statements, as well as certain 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 entity's residual returns, or both. All inter-company balances and transactions are eliminated. The non-controlling interests of the above-mentioned subsidiaries were included in the consolidated balance sheets and statements of 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 issue 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.
F-11

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 in accordance with US GAAP requires that management make estimates and assumptions affecting the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, estimates in respect of residual or scrap value, charter rates, ship operating expenses and drydocking requirements.
In relation to the oil derivative instruments (note 27), the fair value was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the Hilli's Liquefaction Tolling Agreement (“LTA”). The fair value of the gas derivative was determined using the estimated discounted cash flows of the additional payments due to us as a result of forecast natural gas prices and forecast Euro/USD exchange rates. Significant inputs used in the valuation of the oil and gas derivative instruments include 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. The changes in fair value of our oil and gas derivative instruments are recognized in each period within “Realized and unrealized gain/(loss) on oil and gas derivative instruments” as part of the consolidated statement of operations (note 8).
Changes in presentation of Net income/(losses) from equity method investments and Equity method investments
On April 15, 2021, we sold our equity method investments in Golar Partners and Hygo (note 14). Previously, our share of earnings/(losses) in Golar Partners and Hygo and the associated carrying values of our investments in Golar Partners and Hygo were presented within “Net losses from equity method investments” and “Equity method investments”. Following the completion of the disposal, we retrospectively presented our share of earnings/(losses) in Golar Partners and Hygo and the associated carrying values of our investments as “Net income/(loss) from discontinued operations” and “Assets held for sale”, respectively. In addition, we have retrospectively presented the cash flow activities arising from our held for sale investments as “Net cash (used in)/provided by discontinued investing activities”. The retrospective changes in presentation for the prior periods are shown below:

Consolidated Statements of Operations | 2020 |  | 2019
(in thousands of $) | As previously reported | Adjustments Increase/ (Decrease) | Restated |  | As previously reported | Adjustments Increase/ (Decrease) | Restated
Net losses from equity method investments | (176,527) |  | 175,989 |  | (538) |  |  | (45,799) |  | 43,284 |  | (2,515) |
Net loss from discontinued operations | — |  | (175,989) |  | (175,989) |  |  | — |  | (43,284) |  | (43,284) |

Consolidated Balance Sheet | 2020
(in thousands of $) | As previously reported | Adjustments Increase/ (Decrease) | Restated
Equity method investments | 312,151 |  | (267,766) |  | 44,385 |
Assets held for sale | — |  | 267,766 |  | 267,766 |

F-12

Consolidated Statements of Cash Flows | 2020 |  | 2019
(in thousands of $) | As previously reported | Adjustments Increase/ (Decrease) | Restated |  | As previously reported | Adjustments Increase/ (Decrease) | Restated
Net cash provided by operating activities |  |  |  |  |  |  |
Net losses from equity method investments | (176,527) |  | 175,989 |  | (538) |  |  | (45,799) |  | 43,284 |  | (2,515) |
Net loss from discontinued operations | — |  | (175,989) |  | (175,989) |  |  | — |  | (43,284) |  | (43,284) |
Dividend received | — |  | — |  | — |  |  | 7,609 |  | (7,609) |  | — |
Dividend received from discontinued operations | — |  | — |  | — |  |  | — |  | 7,609 |  | 7,609 |
Net cash provided by operating activities | (176,527) |  | — |  | (176,527) |  |  | (38,190) |  | — |  | (38,190) |
Net cash (used in)/provided by investing activities |  |  |  |  |  |  |
Additions to equity method investments | (12,640) |  | 2,410 |  | (10,230) |  |  | (20,994) |  | 19,730 |  | (1,264) |
Dividends received | 10,584 |  | (10,584) |  | — |  |  | 29,207 |  | (29,207) |  | — |
Short-term loan advanced to related parties | (45,000) |  | 45,000 |  | — |  |  | — |  | — |  | — |
Proceeds from repayment of short-term loan advanced to related parties | 45,000 |  | (45,000) |  | — |  |  | — |  | — |  | — |
Proceeds from disposals to Golar Partners, net of cash disposed | — |  | — |  | — |  |  | 9,652 |  | (9,652) |  | — |
Net cash (used in)/provided by investing activities | (2,056) |  | (8,174) |  | (10,230) |  |  | 17,865 |  | (19,129) |  | (1,264) |
Net cash (used in)/provided by discontinued investing activities |  |  |  |  |  |  |
Additions to equity method investments | — |  | (2,410) |  | (2,410) |  |  | — |  | (19,730) |  | (19,730) |
Dividends received | — |  | 10,584 |  | 10,584 |  |  | — |  | 29,207 |  | 29,207 |
Short-term loan advanced to related parties | — |  | (45,000) |  | (45,000) |  |  | — |  | — |  | — |
Proceeds from repayment of short-term loan advanced to related parties | — |  | 45,000 |  | 45,000 |  |  | — |  | — |  | — |
Proceeds from disposals to Golar Partners, net of cash disposed | — |  | — |  | — |  |  | — |  | 9,652 |  | 9,652 |
Net cash (used in)/provided by discontinued investing activities | — |  | 8,174 |  | 8,174 |  |  | — |  | 19,129 |  | 19,129 |

Fair value measurements
We account for fair value measurement in accordance with the accounting standards guidance using fair value to measure assets and liabilities. The guidance provides a single definition of fair value, together with a framework for measuring it, and requires additional disclosure about the use of fair value to measure assets and liabilities.
F-13

Revenue and related expense recognition
Contracts relating to our LNG carriers, FSRUs and FLNG assets can take the form of operating leases, finance leases, tolling agreements and management agreements. In addition, we have historically contracted a portion of our vessels in the spot market through our “Cool Pool” arrangement. Although the substance of these contracts is similar (they allow our customers to hire our assets and to avail themselves of Golar's management services for a specified day rate), the accounting treatment varies.
To determine whether a contract conveys a lease agreement for a period of time, the Company has assessed whether, throughout the period of use, the customer has both of the following:
•the right to obtain substantially all of the economic benefits from the use of the identified asset; and
•the right to direct the use of that identified asset.
If a contract relating to an asset fails to give the customer both of the above rights, we account for the agreement as a revenue contract. A contract relating to an asset will generally be accounted for as a revenue contract if the customer does not contract for substantially all of the capacity of the asset (i.e. another third party could contract for a meaningful amount of the asset capacity).
In situations where we provide management services unrelated to an asset contract, we account for the contract as a revenue contract.
Lease accounting
When a contract is designated as a lease, we make an assessment on whether the contract is an operating lease or a finance lease. An agreement will be a finance lease if any of the following conditions are met:
•ownership of the asset is transferred at the end of the lease term;
•the contract contains an option to purchase the asset which is reasonably certain to be exercised;
•the lease term is for a major part of the remaining useful life of the contract, although contracts entered into the last 25% of the asset's useful life are not subject to this criterion;
•the discounted value of the fixed payments under the lease represents substantially all of the fair value of the asset; or
•the asset is heavily customized such that it could not be used for another charter at the end of the term.
Lessor accounting
In making the classification assessment, we estimate the residual value of the underlying asset at the end of the lease term with reference to broker valuations. None of our lease contracts contain residual value guarantees and any purchase options are disclosed in note 13. Agreements which include renewal and termination options are included in the lease term if we believe they are “reasonably certain” to be exercised by the lessee or if controlled by the lessor. The determination of whether lessee extension clauses are reasonably certain depends on whether the option contains an economic incentive.
Generally, lease accounting commences when the asset is made available to the customer, however, where the contract contains specific customer acceptance testing conditions, lease accounting will not commence until the asset has successfully passed the acceptance test. We assess a lease under the modification guidance when there is a change to the terms and conditions of the contract that results in a change in the scope or the consideration of the lease.
Costs directly associated with the execution of the lease or costs incurred after lease inception (the execution of the contract) but prior to the commencement of the lease that directly 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) to the consolidated balance sheet and amortize to the consolidated statement of income over the lease term.
Fixed revenue from operating leases is accounted for on a straight-line basis over the life of the lease; while variable revenue is accounted for as incurred in the relevant period. Fixed revenue includes fixed payments and variable payments based on a rate or index. For our operating leases, we have elected the practical expedient to combine our service revenue and operating lease income as both the timing and the pattern of transfer of the components are the same.
F-14

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.
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 exposed to significant risk and rewards dependent on the commercial success of the activity. Active participation is deemed to be when participating on the Cool Pool steering committee.
When applying a collaborative arrangement, we present our share of net income earned under the Cool Pool across a number of lines in the Income Statement. 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 Income Statement in the line items “Time and voyage and charter revenues” and “Voyage, charter hire 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 income statement effect for the pooling arrangement.
When no collaborative arrangement is applied, we present our gross share of income earned and costs incurred under the Cool Pool on the face of the Income Statement in the line items “Time and voyage and charter revenues” and “Voyage, charter hire 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, charter hire and commission expenses, net.”
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.
Contractual payment terms for liquefaction services is monthly in arrears. Contract liabilities arise when the customer makes payments in advance of receiving services. The period between when invoicing and when payment is due is not significant.
F-15

Management fees
Management fees are generated from vessel management which includes commercial and technical vessel-related 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, ranging from 30 to 120 days. Contract assets arise when we render management services in advance of entitlement to payment from our customers.
Insurance claims
The Company has two main types of insurance policies, being ‘hull and machinery’ (“H&M”) and ‘loss of hire’ (“LOH”) coverage. LOH indemnifications aim at providing us coverage for loss of revenue for our insured vessels and related claims are 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 Income Statement in the line item “Other operating income”.
H&M policy covers any damage we incur in relation to our property, plant and equipment. The insurance policy is considered loss recoveries, meaning that the timing of recognition of a claim for an insured damage occurs at the time such loss impacts the Income Statement, when deemed probable of being recovered from the counterparty and for an amount net of any deductions that may apply. H&M is recognized on the face of the Income Statement in the 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 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.
Amounts are presented net of allowances for 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 of 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.
F-16

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 relates to our investments on entities over which we generally have between 20% and 50% of the voting rights, or over which we have significant influence, but over which we do not exercise control or have the power to control the financial and operational policies. Investments in these entities are accounted for by the equity method of accounting. This also extends to entities in which we hold a majority ownership interest, but we do not control, due to the other parties' participating rights. Under this method, we record our investment at cost (or fair value if a consequence of deconsolidation), 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 affiliate reduce the carrying amount of the investment. The excess, if any, of the purchase price over book value of our investments in equity method of the affiliates, or basis difference, is included in the consolidated balance sheets as “Equity method investments”. We allocate the basis difference across the assets and liabilities of the affiliate, with the residual assigned to goodwill. Any negative goodwill is recognized immediately in the income statement as a gain on bargain purchase. The basis difference will then be amortized through the consolidated statements of operations as part of the equity method of accounting. When our share of income or losses in equity method investments equals or exceeds its interest, we do not recognize further losses, unless we have incurred obligations or made payments on behalf of the affiliate.
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 building mooring equipment is capitalized and depreciated over the initial lease term of the related agreement.
Refurbishment costs incurred during the period are capitalized as part of vessels and equipment and depreciated over the vessels' remaining useful economic lives. Refurbishment costs are costs that appreciably increase the capacity, or improve the efficiency or safety of vessels and equipment.
Drydocking expenditures are capitalized when incurred and amortized over the period until the next anticipated drydocking, which is generally five years. For vessels that are newly built or acquired, we have adopted the “built-in overhaul” method of accounting. The built-in overhaul method is based on the segregation of vessel costs into those that should be depreciated over the useful life of the vessel and those that require drydocking at periodic intervals to reflect the different useful lives of the components of the assets. The estimated cost of the drydocking component is amortized until the date of the first drydocking following acquisition, upon which the cost is capitalized and the process is repeated. When a vessel is disposed of, any unamortized drydocking expenditure is charged against income in the period of disposal.
F-17

Vessel reactivation costs incurred on vessels leaving lay-up include costs of both a capital and expense nature. The capital costs include the addition of new equipment or modifications to the vessel which enhance or increase the operational efficiency and functionality of the vessel. These expenditures are capitalized and depreciated over the remaining useful life of the vessel. Expenditures of a routine repairs and maintenance nature that do not improve the operating efficiency or extend the useful lives of the vessels are expensed as incurred as mobilization costs.
Useful lives applied in depreciation are as follows:

Vessels (excluding converted 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. Non refundable 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 them ready for their intended use. Qualifying assets consist of vessels under construction, assets under development and vessels undergoing conversion into FSRUs or FLNGs for our own use. In addition, certain equity method investments may be considered qualifying assets prior to commencement of their planned principal operation. The interest capitalized is calculated using the rate of interest on the loan to fund the expenditure or our weighted average cost of borrowings, where appropriate, from commencement of the asset development until substantially all the activities necessary to prepare the assets for its intended use are complete. If our financing plans associate a specific borrowing with a qualifying asset, we use the rate on that borrowing as the capitali z ation rate to be applied to that portion of the average accumulated expenditures for the asset provided that does not exceed the amount of that borrowing. We do not capitali z e amounts beyond the actual interest expense incurred in the period.
Asset retirement obligation
An asset retirement obligation (“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.
F-18

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 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
We continually monitor events and changes in circumstances that could indicate carrying amounts of long-lived assets may not be recoverable. In assessing the recoverability of our vessels’ carrying amounts, we make assumptions regarding estimated future cash flows, 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 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
Where there are indicators that fair value is below carrying value of our investments, we will evaluate these for other-than-temporary impairment. Consideration will be given to (1) the length of time and the extent to which fair value is below carrying value, (2) the financial condition and near-term prospects of the investee, and (3) our intent and ability to hold the investment until any anticipated recovery. Where determined to be other-than-temporary impairment, we will recognize an impairment loss in the period in the line item “Income/(losses) from equity method investments” in the consolidated statements of operations.
F-19

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 losses, net” which is included in net income. We classify our investment in listed equity securities in the income statement 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
Our debt consists 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 and are recorded in interest expense, net of capitalized interest using the effective interest method. Gains and losses on the extinguishment of debt are recorded in other financial items, net on our consolidated statements of operations.
Advances or loans to/from related parties are recorded at cost.
Deferred charges
Costs associated with long-term financing, including debt arrangement fees, are deferred and amortized over the term of the relevant loan under the effective interest method. Amortization of debt issuance costs is included in interest expense. These costs are presented as a deduction from the corresponding liability, consistent with debt discounts.
Derivatives
We use derivatives to reduce market risks associated with our operations. We use interest rate swaps for the management of interest rate risk exposure. The interest rate swaps effectively convert a portion of our debt from a floating to a fixed rate over the life of the transactions without an exchange of underlying principal.
We seek to reduce our exposure to fluctuations in foreign exchange rates through the use of foreign currency forward contracts.
From time to time, we enter into equity swaps. Under these facilities, we swap with our counterparty (usually a major bank) the risk of fluctuations in our share price and the benefit of any dividends, for a fixed payment of LIBOR plus margin. The counterparty may acquire shares in the Company to hedge its own position.
F-20

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 fair value of derivative financial instruments (excluding the oil and gas derivative instruments) are recognized each period in current earnings in “Gains/(losses) on derivative instruments” in the consolidated statements of operations. We do not apply hedge accounting.
The fair value of the oil derivative was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the “LTA”. The fair value of the gas derivative was determined using the estimated discounted cash flows of the additional payments due to us as a result of forecast natural gas prices and forecast Euro/USD exchange rates. Significant inputs used in the valuation of the oil and gas derivative instruments include 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. The changes in fair value of our oil and gas derivative instruments are recognized in each period within “Realized and unrealized gain/(loss) on oil and gas derivative instruments” as part of the consolidated statement of operations.
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
In the ordinary course of business, we are subject to various claims, lawsuits and complaints. Management, in consultation with internal and external advisers, will provide for a contingent loss in the financial statements if the contingency had occurred at the date of the financial statements and the likelihood of loss was probable and the amount can be reasonably estimated. If we determine that the reasonable estimate of the loss is a range and there is no best estimate within the range, we will provide the lower amount within the range.
Pensions
Defined benefit pension costs, assets and liabilities requires the significant actuarial assumptions to be adjusted annually to reflect current market and economic conditions. Our accounting policy states that full recognition of the funded status of defined benefit pension plans is to be included within our consolidated balance sheets. The pension benefit obligation is calculated by using a projected unit credit method.
Defined contribution pension costs represent the contributions payable to the scheme in respect of the accounting period and are recorded in the consolidated statements of operations.
F-21

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 to 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. For those guarantees excluded from the above guidance requiring the fair value recognition for contingent liability, financial statement disclosures of such items are made.
Financial guarantees are assessed for 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 are recognized as a separate component of equity at an amount corresponding to the purchase consideration transferred to repurchase its shares. Upon subsequent disposal of treasury shares, any consideration is recognized directly in equity.
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. We amortize stock-based compensation for awards on a straight-line basis over the period during which the individuals are required to provide service in exchange for the reward - the requisite service (vesting) period. No compensation cost is recognized for stock-based compensation for which the individuals do not render the requisite service. 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 the Company's common stock at grant date.
Earnings per share
Basic earnings per share (“EPS”) is computed based on the income available to common stockholders and the weighted average number of shares outstanding for basic EPS. Treasury shares are not included in the calculation. Diluted EPS includes the effect of the assumed conversion of potentially dilutive instruments. Such potentially dilutive common shares are excluded when the effect would be to increase earnings per share or reduce a loss per share.
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.
F-22

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.
Business combinations
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 given. 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.
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 credit losses, which are calculated using a loss rate applied against an aging matrix.
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. Prior to the sale of our investments in Golar Partners and Hygo, we operated in four reportable segments, “Shipping”, “FLNG”, “Power” and “Corporate and other.” We consider the disposal of our interest in Hygo as our exit from our Power operations and hence ceased to consider Power as a reportable segment (as defined under U.S. GAAP) with effect from the first quarter of 2021. Consequently, management deems that we provide three distinct services and operate in the following three reportable segments: “Shipping”, “FLNG” and “Corporate and other”.

3. | RECENTLY ISSUED ACCOUNTING STANDARDS

Adoption of new accounting standards
In August 2018, the FASB issued ASU 2018-14 Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20). The amendments in this ASU removed certain disclosure requirements and introduced new ones including an explanation of the reasons for significant gains and losses relating to changes in the projected benefit obligation, plan assets to be returned to the entity and accumulated benefit obligation in excess of the fair value of related funding assets. These amendments to disclosure requirements were mandated for defined benefit plans from January 1, 2021. This amendment has not had a material impact on our consolidated financial statements nor related disclosures, including retained earnings, as of January 1, 2021.
In December 2019, the FASB issued ASU 2019-12 Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. The amendments in this ASU removed certain exceptions previously available and provided additional calculation rules to help simplify the accounting for income taxes. These amendments were effective from January 1, 2021. This amendment has not had a material impact on our consolidated financial statements nor related disclosures, including retained earnings, as of January 1, 2021.
F-23

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:

Standard | Description | Date of Adoption | Effect on our Consolidated Financial Statements or Other Significant Matters
ASU 2020-04 Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting; and ASU 2021-01 Reference Rate Reform (Topic 848): Scope. | The amendments provide 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. The applicable expedients for us are in relation to modifications of contracts within the scope of Topics 310, Receivables, 470, Debt, and 842, Leases. This optional guidance may be applied prospectively from any date beginning March 12, 2020 and cannot be applied to modifications that occur after December 31, 2022. | January 1, 2022 | Under evaluation, although all our financial instruments are denominated in U.S. dollars and the reformation date for U.S. dollar settings is not until immediately after June 30, 2023.
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 EPS guidance in ASC 260. | January 1, 2022 | No material impact expected as a result of adoption of this ASU.
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). | The amendments clarify issuer’s recognition and measurement considerations resulting from exchanges or modifications of freestanding instruments (written call options) classified in equity. Such exchanges or modifications are treated as adjustments to the cost to raise debt, to the cost to raise equity or as share-based payments (ASC 718) when issued to compensate for goods or services. If not treated as costs of debt funding, equity funding or share-based payment, it results in an adjustment to EPS/net income/(loss). Holder's accounting is not affected by these amendments. | January 1, 2022 | No material impact expected as a result of adoption of this ASU.

F-24

Standard | Description | Date of Adoption | Effect on our Consolidated Financial Statements or Other Significant Matters
ASU 2021-05 Leases (Topic 842) – Lessors – Certain Leases with Variable Lease Payments | The amendments apply only to lessors and require them to classify leases with variable lease payments that are not based on an index or rate as operating leases if they would have otherwise been classified as sales-type or direct financing leases and the lessor would have recognized a selling loss at lease commencement. There is no change to recognition of variable lease payments. Lessors can apply the amendments either prospectively or retrospectively with accompanying disclosures. | January 1, 2022 | No impact expected as a result of adoption of this ASU.
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.

4. | SUBSIDIARIES

The following table lists our significant subsidiaries and their purpose as at December 31, 2021. 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 Shoreline LNG Limited | Bermuda | Holding company
Golar Hilli LLC (2) | Marshall Islands | Holding company
Golar LNG Energy Limited | Bermuda | Holding company
Golar Hull M2022 Corporation | Marshall Islands | Leases Golar Crystal*
Golar LNG NB10 Corporation | Marshall Islands | Leases Golar Glacier*
Golar Hull M2048 Corporation | Marshall Islands | Leases Golar Ice*
Golar LNG NB11 Corporation | Marshall Islands | Leases Golar Kelvin*
Golar Hull M2021 Corporation | Marshall Islands | Leases Golar Seal*
Golar Hull M2047 Corporation | Marshall Islands | Leases Golar Snow*
Golar Hull M2027 Corporation | Marshall Islands | Leases Golar Bear*

F-25

Name | Jurisdiction of Incorporation | Purpose
Golar Hilli Corp. (2) | Marshall Islands | Leases Hilli Episeyo (“Hilli”)*
Golar LNG NB13 Corporation | Marshall Islands | Owns and operates Golar Tundra
Golar LNG 2216 Corporation | Marshall Islands | Owns and operates Golar Arctic
Golar LNG NB12 Corporation | Marshall Islands | Owns and operates Golar Frost
Golar Gandria N.V. | Curaçao | Owns and operates Golar Gandria
Gimi MS Corporation (3) | Marshall Islands | Owns Gimi
Golar Management (Bermuda) Limited | Bermuda | Management company
Golar Management Limited | United Kingdom | Management company
Golar Management Norway AS | Norway | Vessel management company
Golar Management Malaysia Sdn. Bhd. | Malaysia | Vessel management company
Golar Management D.O.O | Croatia | Vessel management company
Golar Viking Management D.O.O | Croatia | Vessel management company
Golar ML2 LLC | Bermuda | Holding company

(1) In July 2019, Gimi Holding Company Limited was incorporated and is wholly owned by Golar LNG. In October 2019, Golar LNG transferred its ownership in Gimi MS Corporation to Gimi Holding Company Limited.
(2) In February 2018, Golar Hilli LLC was incorporated with Golar LNG as sole member. In June 2018, the 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 Corp. (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 Corporation (“Gimi MS Corp”) was incorporated with Golar LNG as sole shareholder. In February 2019, the Gimi was transferred to Gimi MS Corp 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 Corp. See note 5 for further details.
* The above table excludes mention of the lessor variable interest entities (“lessor VIEs”) that we have leased vessels from under finance leases. The lessor VIEs are wholly-owned, newly formed special purpose vehicles (“SPVs”) of financial institutions. While we do not hold any equity investments in these SPVs, we have concluded that we are the primary beneficiary of these lessor VIEs and accordingly have consolidated these entities into our financial results (note 5).
F-26

5. | VARIABLE INTEREST ENTITIES ("VIEs")

5.1 | Lessor VIEs

As of December 31, 2021, we leased eight vessels (December 31, 2020: nine vessels) from VIEs as part of sale and leaseback agreements, of which four were with ICBC Finance Leasing Co. Ltd (“ICBCL”) entities, one with a CCB Financial Leasing Corporation Limited (“CCBFL”) entity, one with a COSCO Shipping entity, one with a CSSC entity and one with a AVIC International Leasing Company Limited (“AVIC”) entity. Each of the ICBCL, CCBFL, COSCO Shipping, CSSC and AVIC entities are wholly-owned, newly formed special purpose vehicles (“Lessor SPV”). In each of these transactions, we sold our vessel and then subsequently leased back the vessel on a bareboat charter for a term of seven to ten years. We have options to repurchase each vessel at fixed pre-determined amounts during their respective charter periods and an obligation to repurchase each vessel at the end of each vessel's respective lease period.
While we do not hold any equity investments in the above SPVs, we have determined that we have a variable interest in these SPVs and that these lessor entities, that own the vessels, are VIEs. Based on our evaluation of the agreements, we have concluded that we are the primary beneficiary of these VIEs and, accordingly, these lessor VIEs are consolidated into our financial results. We did not record any gains or losses from the sale of these vessels as they continued to be reported as vessels at their original costs in our consolidated financial statements at the time of each transaction. Similarly, the effect of the bareboat charter arrangement is eliminated upon consolidation of the lessor SPV. The equity attributable to the respective lessor VIEs are included in non-controlling interests in our consolidated financial statements. As of December 31, 2021 and 2020, the respective vessels are reported under “Vessels and equipment, net” or “Asset under development” in our consolidated balance sheets.
In November 2015 we entered into a 10 year sale and leaseback arrangement with China Merchants Bank Co. Ltd (“CMBL”) for the Golar Tundra with a sale value of $254.6 million. In December 2021, we repurchased the vessel and terminated the sale and leaseback arrangement with CMBL for $103.3 million and incurred $0.9 million of finance charges. Consequently, this resulted in the deconsolidation of the lessor VIE reflected against non-controlling interest of $25.9 million on our consolidated balance sheet.
The following table gives a summary of the sale and leaseback arrangements, including repurchase options and obligations as of December 31, 2021:

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
Golar Glacier(1) | October 2014 | ICBCL | 204.0 | 10 years | 118.3 | October 2022(2) | 113.4 | April 2023
Golar Kelvin (1) | January 2015 | ICBCL | 204.0 | 10 years | 121.7 | January 2022(2) | 71.0 | January 2025
Golar Snow(1) | January 2015 | ICBCL | 204.0 | 10 years | 126.2 | January 2022(2) | 116.2 | April 2023
Golar Ice (1) | February 2015 | ICBCL | 204.0 | 10 years | 121.2 | February 2022(2) | 71.0 | January 2025
Golar Seal | March 2016 | CCBFL | 203.0 | 10 years | 99.2 | March 2022(2) | 63.4 | March 2026
Golar Crystal | March 2017 | COSCO | 187.0 | 10 years | 85.3 | March 2022(2) | 50.0 | March 2027
Hilli | June 2018 | CSSC | 1,200.0 | 10 years | 611.9 | June 2023 | 300.0 | June 2028
Golar Bear | June 2020 | AVIC | 160.0 | 7 years | 100.1 | March 2022(2) | 35.0 | June 2027

(1) In June 2021, we entered into certain amendments to our ICBCL sale and leaseback facilities which include (i) prepayment of $15.0 million for each sale and leaseback facility in July 2021; and (ii) bringing forward our obligation to repurchase the Golar Glacier and Golar Snow to April 2023 from October 2024 and January 2025, respectively.
(2) W e did not exercise our previous repurchase options.
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A summary of our payment obligations (excluding repurchase options and obligations) under the bareboat charters with the lessor VIEs as of December 31, 2021, are shown below:

(in thousands of $) | 2022 | 2023 | 2024 | 2025 | 2026 | 2027+
Golar Glacier | 17,100 | 4,451 | — | — | — | —
Golar Kelvin | 19,710 | 19,710 | 18,468 | — | — | —
Golar Snow | 17,100 | 3,608 | — | — | — | —
Golar Ice | 19,710 | 19,710 | 19,764 | 162 | — | —
Golar Seal (1) | 13,717 | 13,754 | 13,717 | 13,717 | — | —
Golar Crystal (2) | 10,659 | 10,622 | 10,593 | 10,534 | 10,500 | 1,753
Hilli (2) | 105,509 | 101,717 | 98,016 | 94,133 | 90,341 | 107,583
Golar Bear (2) | 15,755 | 15,153 | 14,562 | 13,949 | 13,347 | 2,721

(1) In November 2021, we entered into another supplementary agreement with the existing lender CCBFL to extend further Golar Seal's put option to January 2025. The last payment obligation relating to the Golar Seal has been presented in 2025 even though the maturity of the lease obligation is in March 2026, given the put option is maturing in January 2025 (note 21).
(2) The payment obligations relating to the Golar Crystal, Hilli and Golar Bear above includes variable rental payments due under the lease based on assumed LIBOR plus a margin.
The assets and liabilities of the lessor VIEs that most significantly impact our consolidated balance sheets as of December 31, 2021 and 2020, are as follows:

(in thousands of $) | Golar Glacier | Golar Kelvin | Golar Snow | Golar Ice | Golar Seal | Golar Crystal | Hilli | Golar Bear | 2021 | 2020
Assets |  |  |  |  |  |  |  |  | Total | Total
Restricted cash and short-term deposits (note 15) | 4,340 |  | 5,068 |  | 4,410 |  | 6,689 |  | 3,432 |  | 4,612 |  | 16,523 |  | 14,156 |  | 59,230 |  | 36,875 |
Liabilities |  |  |  |  |  |  |  |  |  |
Debt: |  |  |  |  |  |  |  |  |  |
Current portion of long-term debt and short-term debt (1) | (82,752) |  | (99,463) |  | (81,906) |  | (54,872) |  | — |  | (8,691) |  | (380,554) |  | — |  | (708,238) |  | (865,982) |
Long-term interest bearing debt - non-current portion (1) | — |  | — |  | — |  | — |  | (78,540) |  | (66,109) |  | (216,313) |  | (104,044) |  | (465,006) |  | (625,119) |
| (82,752) |  | (99,463) |  | (81,906) |  | (54,872) |  | (78,540) |  | (74,800) |  | (596,867) |  | (104,044) |  | (1,173,244) |  | (1,491,101) |

(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, 2021, 2020 and 2019 are as follows:

(in thousands of $) | 2021 | 2020 | 2019
Statement of income |  |  |
Interest expense | 22,670 |  | 34,733 |  | 69,373 |
Statement of cash flows |  |  |
Net debt repayments | (331,929) |  | (550,663) |  | (410,737) |
Net debt receipts | 13,250 |  | 459,707 |  | 144,278 |
Financing costs paid | (1,568) |  | (3,931) |  | — |

F-28

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 (“Hilli Disposal”) to Golar Partners of common units (the “Hilli Common Unit”) in our consolidated subsidiary Golar Hilli LLC (“Hilli LLC”), which owns Golar Hilli Corp. (“Hilli Corp”).
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, the ownership structure of Hilli LLC is as follows:

| Percentage ownership interest
| 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 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 Keppel and B&V’s ownership in Hilli LLC’s Series A Special Units and Series B Special Units as non-controlling interests in our financial statements.
Hilli LLC shall make distributions to the Hilli Unitholders when, as and if declared by us; provided, however, that no distributions may be made on the Hilli Common Units on any distribution date unless Series A Distributions (defined below) and Series B Distributions (defined below) for the most recently ended quarter and any accumulated Series A Distributions and Series B Distributions in arrears for any past quarter have been or contemporaneously are being paid or provided for.
Series A Special Units:
The Series A Special Units rank senior to the Hilli Common Units and on par with the Series B Special Units. Upon termination of the LTA, Hilli LLC has a right to redeem the Series A Special Units from legally available funds at a redemption price of $1 (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 Crude prices rise above $60 per barrel with contractually defined adjustments.
Series B Special Units:
The Series B Special Units rank senior to the Hilli Common Units and on par with the Series A Special Units. There are no conversion or redemption features on the Series B Special Units. Incremental returns generated from future vessel expansion capacity (currently uncontracted and excluding the exercise of additional capacity under the existing LTA) include cash receipts and contractually defined adjustments. Of such vessel expansion capacity distributions (“Series B Distributions”):
•holders of Series B Special Units are entitled to 95% of these distributions, and
•holders of Hilli Common Units are entitled to 5% of these distributions.
Hilli Common Units:
Distributions attributable to Hilli Common Unitholders are not declared until any accumulated Series A Special Units and Series B Special Units distributions have been paid. As discussed above, Hilli Common Unitholders are entitled to receive a pro rata share of 5% of the vessel expansion capacity distributions.
F-29

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, 2021 and 2020, are as follows:

(in thousands of $) | 2021 | 2020
Balance sheet |  |
Current assets | 157,643 |  | 65,629 |
Non-current assets | 1,280,217 |  | 1,203,805 |
Current liabilities | (444,352) |  | (447,701) |
Non-current liabilities | (270,371) |  | (345,058) |

(1) As Hilli LLC is the primary beneficiary of the Hilli Lessor VIE (see above) the Hilli LLC balances include the Hilli Lessor VIE.
The most significant impacts of Hilli LLC VIE's operations on our consolidated statements of operations and consolidated statements of cash flows, as of December 31, 2021 and 2020, are as follows:

(in thousands of $) | 2021 | 2020 | 2019
Statement of operations |  |  |
Liquefaction services revenue | 221,020 |  | 226,061 |  | 218,096 |
Realized and unrealized gain/(loss) on oil and gas derivative instruments | 202,998 |  | (42,561) |  | (26,001) |
Statement of cash flows |  |  |
Net debt repayments | (97,056) |  | (322,304) |  | (243,513) |
Net debt receipts | 2,848 |  | 230,721 |  | 129,454 |

5.3 | Gimi MS Corporation

In April 2019, Gimi MS Corporation (“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 FLNG Gimi. Gimi MS will construct, own and operate FLNG Gimi and First FLNG Holdings subscribed for 30% of the total issued ordinary 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 units, we have determined that (i) Gimi MS is a VIE, (ii) we are the primary beneficiary and retain sole control over the most significant activities and the greatest exposure to variability in residual returns and expected losses from the Gimi. Thus, Gimi MS continues to be consolidated into our financial statements.
Summarized financial information of Gimi MS
The assets and liabilities of Gimi MS that most significantly impacted our consolidated balance sheet as of December 31, 2021 and 2020, are as follows:

(in thousands of $) | Notes | 2021 | 2020
Balance sheet |  |  |
Current assets |  | 7,107 |  | 15,505 |
Non-current assets | 18 | 877,835 |  | 658,247 |
Current liabilities |  | (18,127) |  | (33,844) |
Non-current liabilities |  | (389,244) |  | (277,932) |

F-30

The most significant impacts of Gimi MS VIE's operations on our consolidated statement of cash flows, as of December 31, 2021 and 2020, are as follows:

(in thousands of $) | 2021 | 2020 | 2019
Statement of cash flows |  |  |
Additions to asset under development | 213,481 |  | 217,590 |  | 376,276 |
Financing costs paid | (5,605) |  | (11,302) |  | (20,938) |
Net debt receipts | 110,000 |  | 170,000 |  | 130,000 |
Proceeds from subscription of equity interest | 25,403 |  | 11,081 |  | 115,246 |

6. | SEGMENT INFORMATION

In January 2021, following the board of directors' approvals of the GMLP Merger and Hygo Merger (note 14), we determined that our share of the net earnings/(losses) in Golar Partners and Hygo and the respective carrying values of our equity method investments have to be presented as “Net income/(loss) from discontinued operations” and “Assets held for sale”, respectively. The disposal of our interest in Hygo signaled our exit from Power operations and we ceased to consider the Power operations as a reportable segment (as defined under U.S. GAAP) with effect from the first quarter of 2021. Consequently, management has therefore concluded that we provide and operate three distinct reportable segments as follows:
•Shipping – This segment is based on the business activities of the transportation of LNG carriers. We operate and subsequently charter out LNG carriers on fixed terms to customers.
•FLNG – This segment is based on the business activities of FLNG vessels or projects. We convert LNG carriers into FLNG vessels and subsequently charter them out to customers. We currently have one operational FLNG, the Hilli, one undergoing conversion, the Gimi (note 18), and one LNG carrier earmarked for conversion, the Gandria.
•Corporate and other – This segment is based on the business activities of vessel management and administrative services and our corporate overhead costs.
A reconciliation of net income/(loss) to Adjusted EBITDA for the years ended December 31, 2021, 2020 and 2019 are as follows:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Net income/(loss) | 560,615 |  |  | (167,930) |  |  | (122,375) |
Income taxes | 1,740 |  |  | 981 |  |  | 1,024 |
Income/(loss) before income taxes | 562,355 |  |  | (166,949) |  |  | (121,351) |
Depreciation and amortization | 105,952 |  |  | 107,923 |  |  | 113,033 |
Impairment of long-term assets (1) | — |  |  | — |  |  | 42,098 |
Unrealized (gain)/loss on oil and gas derivative instruments (note 8) | (179,891) |  |  | 45,100 |  |  | 39,090 |
Other non-operating losses/(income), net | 361,928 |  |  | (5,682) |  |  | — |
Interest income | (139) |  |  | (1,572) |  |  | (10,479) |
Interest expense | 55,163 |  |  | 69,354 |  |  | 103,124 |
(Gains)/losses on derivative instruments | (24,348) |  |  | 52,423 |  |  | 38,044 |
Other financial items, net | 759 |  |  | 1,552 |  |  | 5,522 |
Net (income)/losses from equity method investments | (1,080) |  |  | 538 |  |  | 2,515 |
Net (income)/loss from discontinued operations | (568,049) |  |  | 175,989 |  |  | 43,284 |
Adjusted EBITDA | 312,650 |  |  | 278,676 |  |  | 254,880 |

(1) Impairment of long-term assets for the year ended December 31, 2019 include:
•$34.3 million impairment charge on vessel and equipment associated with our LNG carrier, the LNG Croatia;
•$7.3 million impairment charge associated with our investment in OLT Offshore LNG Toscana S.P.A. (“OLT-O”); and
•$0.5 million impairment charge in relation to our investment in Cool Company Ltd.
F-31

| Year Ended December 31, 2021
(in thousands of $) | Shipping | FLNG | Corporate and other (1) | Total results from continuing operations | Results from Discontinued operations | Total
Statement of Operations: |  |  |  |  |  |
Total operating revenues | 202,968 |  | 221,020 |  | 27,777 |  | 451,765 |  | — |  | 451,765 |
Vessel operating expenses | (57,010) |  | (51,196) |  | (12,119) |  | (120,325) |  | — |  | (120,325) |
Voyage, charterhire and commission expenses, net | (10,340) |  | (600) |  | 166 |  | (10,774) |  | — |  | (10,774) |
Administrative expenses (2) | (644) |  | (397) |  | (33,980) |  | (35,021) |  | — |  | (35,021) |
Project development expenses | — |  | (2,974) |  | 187 |  | (2,787) |  | — |  | (2,787) |
Realized gains on oil derivative instrument (note 8) | — |  | 24,772 |  | — |  | 24,772 |  | — |  | 24,772 |
Other operating income | 5,020 |  | — |  | — |  | 5,020 |  | — |  | 5,020 |
Adjusted EBITDA | 139,994 |  | 190,625 |  | (17,969) |  | 312,650 |  | — |  | 312,650 |
Net income/(losses) of equity method investments | — |  | — |  | 1,080 |  | 1,080 |  | 568,049 |  | 569,129 |

(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 Hygo and GMLP Merger Agreements (note 14).

| Year Ended December 31, 2020
(in thousands of $) | Shipping | FLNG | Corporate and other (1) | Total results from continuing operations | Results from Discontinued operations | Total
Statement of Operations: |  |  |  |  |  |
Total operating revenues | 191,881 |  | 226,061 |  | 20,695 |  | 438,637 |  | — |  | 438,637 |
Vessel operating expenses | (57,326) |  | (52,104) |  | 504 |  | (108,926) |  | — |  | (108,926) |
Voyage, charterhire and commission expenses (including expenses from collaborative arrangement) | (12,634) |  | — |  | — |  | (12,634) |  | — |  | (12,634) |
Administrative expenses | (2,211) |  | (1,672) |  | (31,428) |  | (35,311) |  | — |  | (35,311) |
Project development expenses | (112) |  | (2,793) |  | (5,986) |  | (8,891) |  | — |  | (8,891) |
Realized gains on oil derivative instrument (note 8) | — |  | 2,539 |  | — |  | 2,539 |  | — |  | 2,539 |
Other operating income/(losses) | 3,262 |  | — |  | — |  | 3,262 |  | — |  | 3,262 |
Adjusted EBITDA | 122,860 |  | 172,031 |  | (16,215) |  | 278,676 |  | — |  | 278,676 |
Net income/(losses) from equity method investments | — |  | — |  | (538) |  | (538) |  | (175,989) |  | (176,527) |

(1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments.
F-32

| Year Ended December 31, 2019
(in thousands of $) | Shipping | FLNG | Corporate and other (1) | Total results from continuing operations | Results from Discontinued operations | Total
Statement of Operations: |  |  |  |  |  |
Total operating revenues | 208,766 |  | 218,096 |  | 21,888 |  | 448,750 |  | — |  | 448,750 |
Vessel operating expenses | (66,502) |  | (55,284) |  | 496 |  | (121,290) |  | — |  | (121,290) |
Voyage, charterhire and commission expenses (including expenses from collaborative arrangement) | (38,053) |  | (788) |  | — |  | (38,841) |  | — |  | (38,841) |
Administrative expenses | (2,220) |  | (1,526) |  | (48,425) |  | (52,171) |  | — |  | (52,171) |
Project development expenses | (964) |  | (3,173) |  | (853) |  | (4,990) |  | — |  | (4,990) |
Realized gains on oil derivative instrument (note 8) | — |  | 13,089 |  | — |  | 13,089 |  | — |  | 13,089 |
Other operating income/(losses) | 13,295 |  | (2,962) |  | — |  | 10,333 |  | — |  | 10,333 |
Adjusted EBITDA | 114,322 |  | 167,452 |  | (26,894) |  | 254,880 |  | — |  | 254,880 |
Net income/(losses) from equity method investments | — |  | — |  | (2,515) |  | (2,515) |  | (43,284) |  | (45,799) |

(1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments.

| Year Ended December 31, 2021
(in thousands of $) | Shipping | FLNG | Corporate and other (1) | Segment assets from continuing operations | Assets held for sale | Total
Balance sheet: |  |  |  |  |  |
Total assets | 1,811,844 |  | 2,314,342 |  | 822,109 |  | 4,948,295 |  | — |  | 4,948,295 |
Equity method investments | — |  | — |  | 52,215 |  | 52,215 |  | — |  | 52,215 |
Capital expenditures | — |  | 219,582 |  | — |  | 219,582 |  | — |  | 219,582 |

(1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments.
F-33

| Year Ended December 31, 2020
(in thousands of $) | Shipping | FLNG | Corporate and other (1) | Segment assets from continuing operations | Assets held for sale (2)(3) | Total
Balance sheet: |  |  |  |  |  |
Total assets | 1,870,819 |  | 1,933,677 |  | 241,967 |  | 4,046,463 |  | 267,766 |  | 4,314,229 |
Equity method investments | — |  | — |  | 44,385 |  | 44,385 |  | — |  | 44,385 |
Capital expenditures | 101,380 |  | 223,999 |  | — |  | 325,379 |  | — |  | 325,379 |

(1) Includes inter-segment eliminations arising from vessel and administrative management fees revenue between segments.
(2) In 2020, given the continued suppression of Golar Partners' unit price and the significant difference between the carrying value of our investment in Golar Partners and its fair value, we recognized an impairment charge of $135.9 million.. The fair value of our investment in Golar Partners was categorized within level 2 of the fair value hierarchy.
(3) In 2020, we had capitalized interest costs on Hygo amounting to $1.9 million prior to the commencement of the Sergipe Power Plant.
Revenues from external customers
On July 8, 2019, following the exit of GasLog from the Cool Pool, we consolidated the Cool Pool. From the point of consolidation, the Cool Pool ceased to be an external customer, and we no longer use a collaborative arrangement accounting. Consequently, we account for the gross revenue and voyage expenses relating to our vessels in the Cool Pool under “Time and voyage charter revenues” and “Voyage, charterhire and commission expenses”, respectively.
In the years ended December 31, 2021, 2020 and 2019, revenues from the following customers accounted for over 10% of our consolidated time and voyage charter and liquefaction revenues:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Perenco and SNH (1) | 221,020 |  |  | 50 | % |  | 226,061 |  |  | 54 | % |  | 218,096 |  |  | 51 | %
An international major trading house | 70,249 |  |  | 16 | % |  | 46,090 |  |  | 11 | % |  | 25,371 |  |  | 6 | %
A European major trading house | 21,557 |  |  | 5 | % |  | 43,536 |  |  | 10 | % |  | 8,908 |  |  | 2 | %
The Cool Pool (2) | — |  |  | — | % |  | — |  |  | — | % |  | 66,691 |  |  | 16 | %

(1) LTA with Perenco Cameroon S.A. (“Perenco”) and Société Nationale des Hydrocarbures (“SNH”), (together, the “Customer”) in relation to the Hilli (note 7).
(2) The 2019 Cool Pool revenue of $66.7 million includes revenue of $23.4 million that is separately disclosed in the consolidated statements of operations as from a collaborative arrangement. The balance of $43.3 million was derived from Golar vessels operating within the Cool Pool and is included within the caption “Time and voyage charter revenues” in the consolidated statements of operations (note 28).
The revenue table 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 (or our FSRU, operating as a LNG carrier), the charterer, not us, controls the routes of our vessels. These routes can be worldwide as determined by the charterers. Accordingly, the chief operating decision makers do not evaluate our performance either according to customer or geographical region.

(in thousands of $) | 2021 |  | 2020 |  | 2019
Cameroon |  |  |  |  |
Liquefaction services revenue | 221,020 |  |  | 226,061 |  |  | 218,096 |
Total assets | 1,408,444 |  |  | 1,264,085 |  |  | 1,333,779 |

F-34

7. | REVENUE

Contract assets arise when we render services in advance of receiving payment from our customers. Contract liabilities arise when the customer makes payments in advance of receiving the services. Changes in our contract balances during the period are as follows:

(in thousands of $) | Contract assets (1) | Contract liabilities (2)
Opening balance on January 1, 2021 | 26,780 |  | (22,856) |
Payments received for services billed in prior period | (26,780) |  | — |
Services provided and billed in current period | 235,526 |  | — |
Payments received for services billed in current period | (213,748) |  | — |
Deferred commissioning period revenue | — |  | 4,120 |
Closing balance on December 31, 2021 | 21,778 |  | (18,736) |

(1) Relates to management fee revenue and liquefaction services revenue, see a) and b) below.
(2) Relates to liquefaction services revenue, see b) below.
a) Management fee revenue
By virtue of an agreement to offset intercompany balances entered into between us and our related parties, of our total contract asset balances above, $1.0 million and $0.6 million were included in balance sheet line item, “Amounts due from related parties” and “Amounts due to related parties”, respectively as at December 31, 2020 (note 28). Following the completion of the GMLP Merger and Hygo Merger, the agreement to offset intercompany balances between us and our related parties have ceased (note 28).
b) Liquefaction services revenue:
The Hilli is moored in close proximity to the Customer’s gasfields, providing liquefaction service capacity over the term of the LTA. The components of liquefaction services revenue are as follows:

| Year Ended December 31,
(in thousands of $) | 2021 | 2020 | 2019
Base tolling fee (1) | 204,501 |  | 204,501 |  | 204,501 |
Amortization of deferred commissioning period revenue (2) | 4,120 |  | 4,220 |  | 4,220 |
Amortization of Day 1 gain (3) | 9,712 |  | 9,950 |  | 9,950 |
Overproduction revenue (4) | 3,249 |  | 7,965 |  | — |
Other | (562) |  | (575) |  | (575) |
Total | 221,020 |  | 226,061 |  | 218,096 |

(1) The LTA bills at a base rate in periods when the oil price is $60 or less per barrel (included in “Liquefaction services revenue” in the consolidated statements of operations), and at an increased rate when the oil price is greater than $60 per barrel (recognized as a derivative and included in “Realized and unrealized gain/(loss) on oil and gas derivative instruments” in the consolidated statements of operations, excluded from revenue and from the transaction price).
(2) Customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, of $33.8 million is considered an upfront payment for services. These amounts billed were deferred (included in “Other current liabilities” and “Other non-current liabilities” in the consolidated balance sheets) and recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the contract term.
(3) The Day 1 gain was established when the oil derivative instrument was initially recognized in December 2017 for $79.6 million (recognized in “Other current liabilities” and “Other non-current liabilities” in the consolidated balance sheets). This amount is amortized and recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the contract term.
(4) In 2020, we entered into an addendum to the LTA, wherein our Customer, agreed to compensate us for any production in excess of the base capacity set out in the LTA. This resulted in the recognition of overproduction revenues of $3.2 million and $8.0 million included in “Liquefaction services revenue” in the consolidated statements of operations for the years ended December 31, 2021 and 2020.
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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 4.5 years, including the components of transaction price described above.
Hilli increased utilization
In July 2021, we signed an agreement with the Customer to increase the utilization of Hilli (“the Hilli Extended Capacity Agreement”). Commencing in January 2022, the capacity utilization of Hilli will increase by 200,000 tons of LNG, bringing total utilization in 2022 to 1.4 million tons (“2022 Incremental Capacity”). The tolling fee for the 2022 incremental capacity is to be linked to European gas prices at the Dutch Title Transfer Facility (“TTF”) (note 20 and 27). A day 1 gain was established when the gas derivative instrument was initially recognized in July 2021 for $28.6 million (recognized in “Other current assets” and “Other non-current liabilities” in the consolidated balance sheets) and will be recognized as part of “Liquefaction services revenue” in the consolidated statement of operations in 2022.
Under the Hilli Extended Capacity Agreement, the Customer was granted an option to increase capacity utilization of Hilli by up to 400,000 tons of LNG per year from January 2023 through to the end of the current contract term in 2026, which must be declared during the third quarter of 2022 (“2023 Incremental Option”). This has the potential to increase total annual LNG production from Hilli to 1.6 million tons from January 2023 onwards.

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 comprise of the following:

(in thousands of $) | Year Ended December 31,
| 2021 | 2020 | 2019
Realized gain on Hilli oil derivative instrument | 24,772 |  | 2,539 |  | 13,089 |
Unrealized gain/(loss) on Hilli oil derivative instrument (note 20) | 126,940 |  | (45,100) |  | (39,090) |
Unrealized gain on Hilli gas derivative instrument (note 16) | 51,286 |  | — |  | — |
Unrealized mark-to-market adjustment for commodity swap derivatives (note 27) | 1,665 |  | — |  | — |
| 204,663 |  | (42,561) |  | (26,001) |

The unrealized gain/(loss) on oil and gas derivative instruments results from movements in forecast oil, natural gas and Euro/USD exchange rates, whereas the realized gain on oil derivative instrument results from monthly billings above the Hilli base tolling fee under the LTA.

9. | OTHER NON-OPERATING INCOME/(LOSSES)

Other non-operating income/(losses), net comprise of the following:

(in thousands of $) | 2021 |  | 2020 |  |
Unrealized mark-to-market loss on our investment in listed equity securities (note 14 and 27) | 295,777 |  |  | — |  |  |
UK tax lease settlement contingent liability (note 29) | 71,739 |  |  | — |  |  |
Dividend income from our investment in listed equity securities | (5,588) |  |  | — |  |  |
Gain on disposal of the LNG Croatia (note 18) | — |  |  | 5,682 |  |  |
| 361,928 |  |  | 5,682 |  |  |

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10. | GAINS/(LOSSES) ON DERIVATIVE INSTRUMENTS AND OTHER FINANCIAL ITEMS, NET

Gains/(losses) on derivative instruments includes:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Mark-to-market adjustment for interest rate swap derivatives (note 27) | 27,016 |  |  | (38,601) |  |  | (16,485) |
Mark-to-market adjustment for foreign exchange swap derivatives (note 27) | 240 |  |  | (2,556) |  |  | 2,568 |
Interest (expense)/income on undesignated interest rate swaps (note 27) | (2,908) |  |  | (6,215) |  |  | 6,351 |
Mark-to-market adjustment for equity derivatives (note 27) | — |  |  | (5,051) |  |  | (30,478) |
| 24,348 |  |  | (52,423) |  |  | (38,044) |

Other financial items, net includes:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Amortization of debt guarantee (note 28) | 2,569 |  |  | 4,111 |  |  | 1,242 |
Financing arrangement fees and other costs | (2,341) |  |  | (2,138) |  |  | (5,735) |
Foreign exchange loss on operations | (465) |  |  | (3,221) |  |  | (902) |
Other | (522) |  |  | (304) |  |  | (127) |
| (759) |  |  | (1,552) |  |  | (5,522) |

11. | INCOME TAXES

The components of income tax expense are as follows:

| Year ended December 31
(in thousands of $) | 2021 |  | 2020 |  | 2019
Current tax expense | (1,746) |  |  | (809) |  |  | (906) |
Deferred tax expense | 6 |  |  | (172) |  |  | (118) |
Total income tax expense | (1,740) |  |  | (981) |  |  | (1,024) |

The income taxes for the years ended December 31, 2021, 2020 and 2019 differed from the amount computed by applying the Bermuda statutory income tax rate of 0% as follows:

| Year ended December 31
(in thousands of $) | 2021 |  | 2020 |  | 2019
Effect of movement in deferred tax balances | 6 |  |  | (172) |  |  | (118) |
Effect of adjustments in respect of current tax in prior periods | (224) |  |  | (37) |  |  | (86) |
Effect of taxable income in various countries | (1,522) |  |  | (772) |  |  | (820) |
Total tax expense | (1,740) |  |  | (981) |  |  | (1,024) |

Jurisdictions open to examination
The earliest tax years that remain subject to examination by the major taxable jurisdictions in which we operate are: 2020 (UK) and 2017 (Norway).
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, 2021, we have a deferred tax liability of $0.6 million (2020: $0.6 million).
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12. | EARNINGS/(LOSS) PER SHARE

Basic earnings/(loss) per share (“EPS”) is calculated with reference to the weighted average number of common shares outstanding during the year.
The components of the numerator for the calculation of basic and diluted EPS are as follows:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Net loss attributable to Golar LNG Ltd stockholders from continuing operations - basic and diluted | (154,198) |  |  | (97,568) |  |  | (168,672) |
Net income/(loss) from discontinued operations - basic and diluted | 568,049 |  |  | (175,989) |  |  | (43,284) |

The components of the denominator for the calculation of basic and diluted EPS are as follows:

(in thousands) | 2021 |  | 2020 |  | 2019
Basic and diluted loss per share: |  |  |  |  |
Weighted average number of common shares outstanding | 108,208 |  |  | 96,983 |  |  | 100,659 |

EPS are as follows:

| 2021 |  | 2020 |  | 2019
Basic and diluted EPS from continuing operations (1) | $ | (1.43) |  |  | $ | (1.01) |  |  | $ | (1.68) |
Basic and diluted EPS from discontinued operations | $ | 5.25 |  |  | $ | (1.81) |  |  | $ | (0.43) |

(1) The effects of stock awards and convertible bonds have been excluded from the calculation of diluted EPS for each of the years ended December 31, 2021, 2020 and 2019 because the effects were anti-dilutive.

13. | OPERATING LEASES

Rental income
The minimum contractual future revenues to be received on time charters in respect of our vessels as of December 31, 2021, were as follows:

Year ending December 31 |
(in thousands of $) |
2022 | 173,829 |
2023 | 55,785 |
2024 | 34,322 |
2025 | 22,174 |
2026 and thereafter | 22,807 |
Total minimum contractual future revenues | 308,917 |

The cost and accumulated depreciation of vessels leased to third parties at December 31, 2021 and 2020 were $2,149.0 million and $2,149.1 million; and $413.0 million and $356.0 million, respectively. With the exception of the Hilli which has a carrying value of $1,119.2 million as of December 31, 2021 and 2020. In April 2022, we consummated the Vessel Sale and Purchase Agreement (the “Vessel SPA”) with Cool Company Ltd (“Cool Co”) resulting to the disposal of eight of our vessels (note 30).
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The components of operating lease income were as follows:

(in thousands of $) | 2021 | 2020 | 2019
Operating lease income(1) | 185,318 |  | 186,706 |  | 123,292 |
Variable lease income (1) (2) | 17,650 |  | 5,175 |  | 18,783 |
Total operating lease income | 202,968 |  | 191,881 |  | 142,075 |

(1) “Total operating lease income” is included in the income statement line-item “Time and voyage charter revenues”. During the year ended December 31, 2021 and 2020, we chartered in an external vessel and recognized $0.9 million and $4.6 million of operating lease income, respectively and $2.6 million of variable lease income for the year ended December 31, 2021. No similar external vessel was chartered for the year ended December 31, 2019.
(2) “Variable lease income” is excluded from lease payments that comprise the minimum contractual future revenues from non-cancellable operating leases.
Rental expense
We lease certain office premises, equipment on-board our fleet of vessels and service boats supporting the Hilli under operating leases. Many lease agreements include one or more options to renew. We will include these renewal options when we are reasonably certain that we will exercise the option. The exercise of these lease renewal options is at our discretion.
Variable lease cost relates to certain of our lease agreements which include payments that vary. These are primarily generated from service charges related to our usage of office premises, usage charges for equipment on-board our fleet of vessels, adjustments for inflation, and fuel consumption for the rental of service boats supporting the Hilli.
The components of operating lease cost were as follows:

(in thousands of $) | 2021 | 2020 | 2019
Operating lease cost (1) | 9,628 |  | 8,951 |  | 5,603 |
Variable lease cost (2) | 1,621 |  | 4,000 |  | 2,983 |
Total operating lease cost | 11,249 |  | 12,951 |  | 8,586 |

(1) “Operating lease cost” includes short-term lease cost. During the year ended December 31, 2021 and 2020, we sub-chartered out an external vessel and recognized $3.0 million and $3.8 million of cost respectively, presented in the income statement line-item “Voyage, charterhire and commission expense”. No similar external vessel was chartered for the year ended December 31, 2019.
(2) “Variable lease cost” is excluded from lease payments that comprise the operating lease liability.
Total operating lease cost is included in the income statement line-items “Vessel operating expenses” and “Administrative expenses”.
As of December 31, 2021 and 2020 the right-of-use assets recognized by Golar as a lessee in various operating leases amounted to $11.0 million and $14.6 million respectively (note 20).
Our weighted average remaining lease term for our operating leases is 5.0 years. Our weighted-average discount rate applied for the majority of our operating leases is 5.5%.
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The maturity of our lease liabilities is as follows:

Year ending December 31 |
(in thousands of $) |
2022 | 3,838 |
2023 | 2,051 |
2024 | 1,589 |
2025 | 1,725 |
2026 and thereafter | 2,528 |
Total minimum lease payments | 11,731 |

Total rental expense for operating leases was $11.2 million, $13.0 million and $8.6 million for the years ended December 31, 2021, 2020 and 2019, respectively.

14. | DISCONTINUED OPERATIONS

Golar Partners
Golar Partners is an owner and operator of FSRUs and LNG carriers and we had previously accounted for all our investments (Common Units, GP Units and incentive distribution rights (“IDRs”)) in Golar Partners under the equity method since the deconsolidation of Golar Partners in December 2012.
On April 15, 2021, we completed the Agreement and Plan of Merger (the “GMLP Merger Agreement”) with NFE, Golar GP LLC, the general partner of Golar Partners (the “General Partner”), Lobos Acquisition LLC, a limited liability company and a wholly-owned subsidiary of NFE (“GMLP Merger Sub”), and NFE International Holdings Limited, a private limited company and a wholly-owned subsidiary of NFE (“GP Buyer”). GMLP Merger Sub merged with and into Golar Partners (the “GMLP Merger”), with Golar Partners surviving the GMLP Merger as a wholly-owned subsidiary of NFE. Under the GMLP Merger Agreement, NFE acquired all the outstanding common units of Golar Partners for $3.55 per unit in cash. Concurrently with the completion of the GMLP merger, the IDRs of Golar Partners owned by us were cancelled and ceased to exist, and no consideration was paid to us in respect thereof.
Hygo
Hygo was a joint venture with private equity firm Stonepeak and owned a 50% interest in Centrais Eléctricas de Sergipe S.A. (“CELSE”), which operates the Sergipe Power Plant. We had previously considered Hygo and its subsidiaries as our affiliates and accordingly accounted for our investment in Hygo under the equity method of accounting since the formation of the joint venture in 2016.
On April 15, 2021, we also completed the Agreement and Plan of Merger (the “Hygo Merger Agreement”) with NFE, Hygo, Stonepeak Infrastructure Fund II Cayman (G) Ltd., a fund managed by Stonepeak, and Lobos Acquisition Ltd., a wholly-owned subsidiary of NFE (“Hygo Merger Sub”), pursuant to which, on April 15, 2021, Hygo Merger Sub merged with and into Hygo (the “Hygo Merger”), with Hygo surviving the Hygo Merger as a wholly owned subsidiary of NFE. Under the terms of the Hygo Merger Agreement, NFE acquired all the outstanding shares of Hygo for 31,372,549 Class A NFE common shares and $580 million in cash of which we received consideration of $50 million in cash and 18,627,451 NFE Shares.
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Gain on disposal of Golar Partners and Hygo
Gain on disposal of our equity accounted investments in Golar Partners and Hygo to NFE is determined as follows:

(in thousands of $) |
Consideration received from NFE (1)(2) | 876,277 |
Carrying value of disposed equity method investments(3) | (257,270) |
Realized accumulated comprehensive losses on disposal of equity method investment | (43,380) |
Others (4) | (686) |
Gain on disposal | 574,941 |

(1) Consideration received from NFE comprised of (i) $75.7 million and $5.1 million in cash as consideration for our 21,333,586 Golar Partners common units and the 2% general partner units of Golar Partners respectively, which is equivalent to $3.55 per unit on the closing of the GMLP Merger. Concurrently, the IDRs of Golar Partners owned by us were cancelled, ceased to exist with no consideration paid; and (ii) $50.0 million cash and $745.4 million as the fair value of NFE Shares on closing of the Hygo Merger.
(2) On closing of the Hygo Merger, consideration received include $50 million in cash and 18,627,451 NFE Shares. The NFE Shares had a closing price of $44.65 on April 15, 2021, however these shares bore a restricted legend which became freely tradable from October 16, 2021. We have considered this restriction to be a characteristic of the instrument and have adjusted the fair value of our investment to reflect the effect of this restriction. To reflect the lack of marketability of the NFE Shares during its holding period, we applied a discount of 10.37%, using the average of several option pricing valuation models. This resulted in a fair value of $745.4 million at April 15, 2021. The key assumptions used in the option pricing model include dividend yield, equity volatility and equity beta relating to the NFE Shares, market volatility and equity market risk premium.
As of December 31, 2021, NFE's closing share price of $24.14 resulted in a fair value of $449.7 million and a total unrealized mark-to-market loss of $295.8 million, presented within the income statement line-item “Other non-operating losses, net” (note 9).
(3) The carrying value of our equity method investments at the date of disposal were made up of (i) $267.8 million book value as of December 31, 2020; (ii) $6.9 million share in net losses from our equity method investments' operations for the period from January 1, 2021 to April 15, 2021; (iii) $3.1 million of other comprehensive loss for the period from January 1, 2021 to April 15, 2021; and (iv) $0.5 million of dividends received.
(4) Others comprised of fees incurred in relation to the disposal of our equity method investments and the release of our tax indemnity guarantee liability to Golar Partners of $2.8 million and $2.1 million, respectively.
Net income/(loss) from discontinued operations
The net income/(loss) from discontinued operations for the period ended April 15, 2021 and the year ended December 31, 2020, are as follows:

| Year ended December 31
(in thousands of $) | 2021 | 2020 | 2019
Share of net earnings/(losses) of Golar Partners (1) | 8,116 |  | (136,832) |  | (20,050) |
Share of net losses of Hygo (1) | (15,008) |  | (39,157) |  | (23,234) |
Loss from discontinued operations (1) | (6,892) |  | (175,989) |  | (43,284) |
Gain on disposal of equity method investments | 574,941 |  | — |  | — |
Net income/(loss) from discontinued operations | 568,049 |  | (175,989) |  | (43,284) |

(1) For the period ended April 15, 2021.
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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 |
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
Under the indemnity agreement, we and Stonepeak have agreed on a several (but not joint) basis (i) to indemnify Hygo in respect of its obligations under its guarantee of certain obligations related to CELSE (such indemnity not to exceed $3 million) and (ii) in connection therewith, to procure the delivery of a letter of credit with a face value of $1.5 million (note 15). Under the Hygo omnibus agreement, Golar agreed to guarantee the certain obligations of the sale leaseback arrangements in respect of the Golar Celsius, Golar Penguin and Golar Nanook. 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 Golar Hilli Corporation. 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 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.
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For the period from April 15, 2021 to December 31, 2021, we:
•declared distributions on Hilli LLC totaling $21.2 million with respect to the Hilli LLC common units owned by Golar Partners and accounted for $0.1 million of Hilli costs indemnification;
•incurred pool net expenses from other participants in the pooling arrangement totaling $2.5 million;
•earned ship management and administrative services fees from Golar Partners and Hygo amounting to $10.0 million; and
•earned charter and debt guarantee fees from Golar Partners and Hygo amounting to $1.4 million. As of December 31, 2021, we guaranteed $387.3 million of Hygo's gross long-term debt obligations.

15. | RESTRICTED CASH AND SHORT-TERM DEPOSITS

Our restricted cash and short-term deposits balances are as follows:

(in thousands of $) | 2021 |  | 2020
Restricted cash in relation to the Hilli (1) | 60,720 |  |  | 77,212 |
Restricted cash and short-term deposits held by lessor VIEs (2) | 59,230 |  |  | 36,875 |
Restricted cash in relation to liability for UK tax leases (3) | 16,000 |  |  | — |
Restricted cash relating to sale of LNG Croatia (4) | 11,328 |  |  | — |
Restricted cash related to Hygo performance guarantee (5) | 1,500 |  |  | — |
Restricted cash relating to office lease | 782 |  |  | 868 |
Restricted cash relating to the $1.125 billion debt facility (6) | 605 |  |  | 2,615 |
Restricted cash relating to interest rate swaps (7) | — |  |  | 8,864 |
Restricted cash relating to disposal of LNG Croatia (8) | — |  |  | 36,747 |
Total restricted cash and short-term deposits | 150,165 |  |  | 163,181 |
Less: Amounts included in current restricted cash and short-term deposits | (77,337) |  |  | (100,361) |
Long-term restricted cash | 72,828 |  |  | 62,820 |

(1) In November 2015, in connection with the issuance of a $400 million letter of credit (“LC”) by a financial institution to our project partner involved in the Hilli FLNG project, we posted an initial cash collateral sum of $305.0 million to support the Hilli performance guarantee. Under the provisions of the $400 million LC, the terms allow for a stepped reduction in the value of the guarantee over time and thus, a concurrent reduction in the cash collateral requirements. In May 2021, following the achievement of the 3.6 million tonnes of LNG production milestone, the LC was reduced to $100 million and the cash collateral to $60.7 million.
In November 2016, after certain conditions precedent were satisfied by the Company, the LC required in accordance with the signed LTA was re-issued and, with an initial expiry date of December 31, 2018, the LC automatically extends, on an annual basis, until the tenth anniversary of the acceptance date of the Hilli by the charterer, unless the bank should exercise its option to exit from this arrangement by giving three months' notice prior to the annual renewal date.
(2) These are amounts held by lessor VIE entities that we are required to consolidate under U.S. GAAP into our financial statements as VIEs (note 5).
(3) The lessor for the six UK leases has 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 and a collateral of $16.0 million (note 29).
(4) In connection with the Operation & Maintenance Agreement (“LNG Hrvatska O&M Agreement”) that we entered with LNG Hrvatska d.o.o. to operate and maintain the FSRU, LNG Croatia, we are required to hold a performance guarantee of €9.3 million and $1.3 million, which will remain restricted throughout the 10-year O&M Agreement term.
(5) In connection with the disposal of Hygo, we provided a $1.5 million performance guarantee to the senior lenders of CELSE to enable the lenders to waive their requirement for consent in the event of a change of control and extend the technical completion date. The guarantee expired in January 2022.
(6) At December 31, 2021, the remaining balance in the $1.125 billion facility only relates to the Golar Frost amounting to $54.7 million with a cash collateral of $0.6 million.
(7) This refers to the collateral required by certain banks for some of our interest rate swaps that have a credit arrangement which requires us to provide cash collateral when the market value of the instrument falls below a specified threshold.
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(8) In December 2020, as part of the sale of LNG Croatia, $36.7 million (€30.0 million) was required to be held in an escrow account and was subsequently released 30 days post-acceptance of the vessel (note 18).
Restricted cash does not include minimum consolidated cash balances of $50.0 million (note 21) required to be maintained as part of the financial covenants for our loan facilities, as these amounts are included in “Cash and cash equivalents”.

16. | OTHER CURRENT ASSETS

Other current assets consists of the following:

(in thousands of $) | 2021 |  | 2020
Investment in listed equity securities (1) | 450,225 |  |  | — |
Gas derivative instrument (note 27) | 79,578 |  |  | — |
TTF swap collateral (2) | 6,940 |  |  | — |
Prepaid expenses | 3,567 |  |  | 2,391 |
Mark-to-market asset on TTF swap (note 27) | 1,753 |  |  | — |
Other receivables | 3,801 |  |  | 6,291 |
| 545,864 |  |  | 8,682 |

(1) “Investment in listed equity securities” is comprised of our 18.6 million NFE Shares (note 14 and 27), and associated dividend receivable from these shares, amounting to $449.7 million and $0.6 million, respectively. Dividend receivable is included in the income statement line-item “Other non-operating losses, net”.
(2) TTF swap collateral relates to the amount required by the swap counterparty, held at measurement date, reactive to the daily fluctuations of the market value of the financial instrument.

17. | EQUITY METHOD INVESTMENTS

On April 15, 2021 we completed the GMLP and Hygo Mergers and retrospectively presented our share of earnings/(losses) in Golar Partners and Hygo, and the associated carrying values of our equity accounted investments as net income/(loss) from discontinued operations (note 14).
At December 31, 2021 and 2020, we have the following participation in investments that are recorded using the equity method:

| 2021 |  | 2020
Egyptian Company for Gas Services S.A.E (“ECGS”) | 50.0 | % |  | 50.0 | %
Avenir LNG Limited (“Avenir”) | 23.5 | % |  | 23.1 | %

The carrying amounts of our investments in our equity method investments as at December 31, 2021 and 2020 are as follows:

(in thousands of $) | 2021 |  | 2020
Avenir | 47,913 |  |  | 39,984 |
ECGS | 4,302 |  |  | 4,401 |
Total equity method investments | 52,215 |  |  | 44,385 |

The components of our equity method investments are as follows:

(in thousands of $) | 2021 |  | 2020
Balance as of January 1 | 44,385 |  |  | 32,816 |
Additions | 6,750 |  |  | 11,250 |
Capitalized interest | — |  |  | 857 |
Net income/(losses) from equity method investments | 1,080 |  |  | (538) |
Balance as at December 31 | 52,215 |  | 44,385

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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”), Höegh LNG Holdings Limited (“Höegh”) entered into a joint $182.0 million investment in Avenir. Golar had 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.
In March 2020, Avenir issued an equity shortfall notice of $45.0 million which was funded through issuance of additional shares at a par value of $1.00 per share. As of December 31, 2021, we had fully injected our committed equity of $18.0 million to Avenir, bringing our total contribution to Avenir of $42.75 million, representing 23.5% ownership.
Interest costs capitalized on the investment in Avenir for the years ended December 31, 2021 and 2020, were $nil and $0.9 million respectively.

18. | ASSET UNDER DEVELOPMENT

(in thousands of $) | 2021 | 2020
As of January 1 | 658,247 |  | 434,248 |
Additions | 178,377 |  | 283,927 |
Transfer from vessels and equipment, net (note 19) | — |  | 77,172 |
Transfer from other non-current assets (1) | — |  | 16,213 |
Interest costs capitalized | 41,214 |  | 34,296 |
Disposal of LNG Croatia | — |  | (187,609) |
As of December 31 | 877,838 |  | 658,247 |

(1) In January 2020, the net book value of LNG Croatia was classified to asset under development as well as the associated long lead items of $16.2 million, following her entry to the shipyard for FSRU conversion.
Gimi FLNG conversion
In February 2019, we entered into a Lease and Operate Agreement (“LOA”) with BP for the employment of a FLNG unit, Gimi, after conversion to an FLNG for a term of 20 years. In April 2019, we completed the sale of 30% of the total issued ordinary share capital of Gimi MS to First FLNG Holdings. 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. The conversion cost including financing cost is approximately $1.6 billion of which $700 million is funded by the Gimi facility (note 21).
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As of December 31, 2021, the estimated timing of the outstanding payments in connection with the Gimi FLNG conversion are as follows:

(in thousands of $) |
Period ending December 31, |
2022 | 372,792 |
2023 | 285,358 |
2024 | 57,346 |
| 715,496 |

LNG Croatia FSRU conversion
In March 2019, we entered into agreements with LNG Hrvatska relating to the conversion and subsequent sale of the converted carrier LNG Croatia into a FSRU. In January 2020, LNG Croatia entered the yard for conversion. Concurrently, we entered into a sale and leaseback agreement with CSSC to fund the FSRU conversion and had drawn down $124.7 million during 2020. In addition, we also entered into the LNG Hrvatska O&M Agreement in relation to the converted FSRU LNG Croatia for a minimum of 10 years, with renewal options. In December 2020, upon acceptance of the converted FSRU LNG Croatia, we repurchased the vessel and settled in full our sale and leaseback obligations with CSSC.
The table below shows the gain on disposal of the LNG Croatia recognized in December 2020 under “Other non-operating income”:

(in thousands of $) | 2020
Cash consideration received | 193,291 |
Carrying value of converted vessel, LNG Croatia | (187,609) |
Gain on disposal | 5,682 |

19. | VESSELS AND EQUIPMENT, NET

| Year Ended December 31, 2021
(in thousands of $) | Vessels and equipment | Mooring equipment | Deferred Drydocking expenditure | Office equipment and fittings | Total
Cost |  |  |  |  |
As of January 1 | 3,298,854 |  | 45,771 |  | 137,951 |  | 8,166 |  | 3,490,742 |
Additions | — |  | — |  | — |  | 87 |  | 87 |
Write-offs (1) | (87) |  | — |  | — |  | (96) |  | (183) |
As of December 31 | 3,298,767 |  | 45,771 |  | 137,951 |  | 8,157 |  | 3,490,646 |
Depreciation, amortization and impairment |  |  |  |  |
As of January 1 | (465,206) |  | (14,820) |  | (23,014) |  | (4,629) |  | (507,669) |
Charge for the year (2) | (86,238) |  | (5,543) |  | (12,587) |  | (1,118) |  | (105,486) |
Write-offs (1) | 87 |  | — |  | — |  | 96 |  | 183 |
As of December 31 | (551,357) |  | (20,363) |  | (35,601) |  | (5,651) |  | (612,972) |
Net book value as at December 31, 2021 | 2,747,410 |  | 25,408 |  | 102,350 |  | 2,506 |  | 2,877,674 |

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| Year Ended December 31, 2020
(in thousands of $) | Vessels and equipment | Mooring equipment | Deferred Drydocking expenditure | Office equipment and fittings | Total
Cost |  |  |  |  |
As of January 1 | 3,429,317 |  | 45,771 |  | 140,738 |  | 8,398 |  | 3,624,224 |
Additions | 3,282 |  | — |  | 3,713 |  | 161 |  | 7,156 |
Transfer to asset under development (3) | (127,620) |  | — |  | — |  | — |  | (127,620) |
Write-offs (1) | (6,125) |  | — |  | (6,500) |  | (393) |  | (13,018) |
As of December 31 | 3,298,854 |  | 45,771 |  | 137,951 |  | 8,166 |  | 3,490,742 |
Depreciation, amortization and impairment |  |  |  |  |
As of January 1 | (434,396) |  | (9,106) |  | (16,434) |  | (3,739) |  | (463,675) |
Charge for the year | (87,383) |  | (5,714) |  | (13,080) |  | (1,283) |  | (107,460) |
Transfer to asset under development (3) | 50,448 |  | — |  | — |  | — |  | 50,448 |
Write-offs (1) | 6,125 |  | — |  | 6,500 |  | 393 |  | 13,018 |
As of December 31 | (465,206) |  | (14,820) |  | (23,014) |  | (4,629) |  | (507,669) |
Net book value as at December 31, 2020 | 2,833,648 |  | 30,951 |  | 114,937 |  | 3,537 |  | 2,983,073 |

(1) Write-offs relates to fully depreciated or fully amortized assets.
(2) Depreciation and amortization charge for the years ended December 31, 2021 and 2020, excludes $0.5 million and, $0.5 million respectively, of amortization charges in relation to the Cameroon License fee.
(3) Relates to the reclassification of LNG Croatia's carrying value and associated accumulated depreciation to “Asset under development” (note 18).
The following table presents the market values and carrying values of our vessels that we have determined to have market values that are less than their carrying values as of December 31, 2021. However, based on the estimated future undiscounted cash flows of these vessels, which are significantly greater than the respective carrying values, no impairment was recognized.
(in millions of $)

Vessel | 2021 Market value (1) | 2021 Carrying value | Deficit
Golar Arctic | 42.0 | 123.2 | (81.2)
Golar Bear | 156.0 | 172.8 | (16.8)
Golar Crystal | 155.5 | 167.8 | (12.3)
Golar Frost | 156.5 | 175.8 | (19.3)
Golar Glacier | 158.0 | 172.0 | (14.0)
Golar Ice | 160.8 | 179.2 | (18.4)
Golar Kelvin | 160.3 | 173.5 | (13.2)
Golar Seal | 153.3 | 163.0 | (9.7)
Golar Snow | 161.8 | 179.2 | (17.4)

(1) Market values are determined using reference to average broker values provided by independent brokers. Broker values are considered an estimate of the market value for the purpose of determining whether an impairment trigger exists. Broker values are commonly used and accepted by our lenders in relation to determining compliance with relevant covenants in applicable credit facilities for the purpose of assessing security quality.
Since vessel values can be volatile, our estimates of market value may not be indicative of either the current or future prices we could obtain if we sold any of the vessels. In addition, the determination of estimated market values may involve considerable judgment, given the illiquidity of the second-hand markets for these types of vessels.
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20. | OTHER NON-CURRENT ASSETS

Other non-current assets comprised of the following:

(in thousands of $) | 2021 |  | 2020
Oil derivative instrument (note 27) | 127,480 |  |  | 540 |
Operating lease right-of-use-assets (1) | 10,991 |  |  | 14,642 |
Other non-current assets (2) | 3,672 |  |  | 12,729 |
| 142,143 |  |  | 27,911 |

(1) Operating lease right-of-use-assets mainly comprise of our office leases.
(2) Included in “other non-current assets” for the year ended December 31, 2020 was the compensation of the debt guarantees provided to Hygo of $8.1 million. Following the completion of the Hygo Merger, the debt guarantees were terminated and replaced with a transition services agreement (note 14).

21. | DEBT

(in thousands of $) | 2021 |  | 2020
Total debt, net of deferred finance charges | (2,409,801) |  |  | (2,350,782) |
Less: Current portion of long-term debt and short-term debt | 1,051,582 |  |  | 982,845 |
Long-term debt | (1,358,219) |  |  | (1,367,937) |

The outstanding debt, gross of deferred finance charges, as of December 31, 2021 is repayable as follows:

Year ending December 31 | Golar debt |  | VIE debt (1) |  | Total debt
(in thousands of $) |  |  |  |  |
2022 | (343,793) |  |  | (708,758) |  |  | (1,052,551) |
2023 | (28,147) |  |  | (173,085) |  |  | (201,232) |
2024 | (101,074) |  |  | (68,279) |  |  | (169,353) |
2025 | (367,646) |  |  | (146,819) |  |  | (514,465) |
2026 | (176,691) |  |  | (42,448) |  |  | (219,139) |
2027 and thereafter | (249,583) |  |  | (35,602) |  |  | (285,185) |
Total | (1,266,934) |  |  | (1,174,991) |  |  | (2,441,925) |
Deferred finance charges | 30,377 |  |  | 1,747 |  |  | 32,124 |
Total debt net of deferred finance charges | (1,236,557) |  |  | (1,173,244) |  |  | (2,409,801) |

(1) These amounts relate to certain lessor entities (for which legal ownership resides with financial institutions) that we are required to consolidate under U.S. GAAP into our financial statements as variable interest entities (note 5).
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At December 31, 2021 and 2020, our debt was as follows:

(in thousands of $) | 2021 | 2020 | Maturity date
Golar Arctic facility | (29,178) |  | (36,472) |  | 2024
2017 Convertible bonds | (315,646) |  | (383,739) |  | 2022
Norwegian bonds | (299,403) |  | — |  | 2025
Golar Tundra facility | (158,000) |  | — |  | 2026
Revolving Credit Facility | — |  | (100,000) |  |
Gimi Facility | (410,000) |  | (300,000) |  | 2030
$1,125 billion facility: |  |  |
- Golar Frost facility | (54,707) |  | (65,649) |  | 2024 (1)
Subtotal (excluding lessor VIE loans) | (1,266,934) |  | (885,860) |  |
ICBCL VIE loans: |  |  |
- Golar Glacier facility | (82,816) |  | (110,625) |  | Repayable on demand
- Golar Snow facility | (81,970) |  | (111,108) |
- Golar Kelvin facility | (99,538) |  | (128,562) |
- Golar Ice facility | (54,947) |  | (83,857) |
CMBL VIE loan: |  |  |
- Golar Tundra facility | — |  | (89,450) |  |
CCBFL VIE loan: |  |  |
- Golar Seal facility | (78,540) |  | (90,178) |  | 2025
COSCO VIE loan: |  |  |
- Golar Crystal facility | (75,094) |  | (83,596) |  | 2027
CSSC VIE loan: |  |  |
- Hilli facility | (597,280) |  | (691,488) |  | Repayable on demand/2026
AVIC VIE loan: |  |  |
Golar Bear facility | (104,806) |  | (104,807) |  | 2023
Total debt (gross) | (2,441,925) |  | (2,379,531) |  |
Deferred finance charges | 32,124 |  | 28,749 |  |
Total debt net of deferred finance charges | (2,409,801) |  | (2,350,782) |  |

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 5 years from execution, is repayable in quarterly installments and has a final balloon 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. The conversion rate for the bonds was initially equal to 26.5308 common shares per $1,000 principal amount of the bonds. This is equivalent to an initial conversion price of $37.69 per common share, or a 35% premium on the February 13, 2017 closing share price of $27.92. The conversion price is subject to adjustment for dividends paid. To mitigate the dilution risk of conversion to common equity, we also entered into capped call transactions costing approximately $31.2 million. The capped call transactions cover approximately 10,678,647 common shares, have an initial strike price of $37.69, and an initial cap price of $48.86. The cap price of $48.86, which is a proxy for the revised conversion price, represents a 75% premium on the February 13, 2017 closing share price of $27.92. Including the $31.2 million cost of the capped call, the all-in cost of the bond is approximately 4.3%. Bond proceeds, net of fees and the cost of the capped call, amounted to $360.2 million. On inception, we recognized a liability of $320.3 million and an equity portion of $39.9 million.
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During 2019, the quarterly dividends of the following quarter results exceeded the dividend threshold and resulted in an adjustment to the initial conversion rate.

In $, except conversion rate |  |  |
| Distribution declared per share | Conversion rate | Conversion price
First quarter, 2019 | 0.150 |  | 26.993 |  | 37.05 |

Norwegian Bonds
In October 2021, we closed our $300.0 million senior unsecured bonds in the Nordic bond market (“Norwegian Bonds”). The Norwegian Bonds will mature in October 2025 and bear interest at 7.00% per annum. The net proceeds from the Norwegian Bonds was used to partly refinance our $402.5 million million 2017 convertible bonds maturing in February 2022 (“Convertible Bonds”) and for general corporate purposes. Contemporaneous with the closing of the Norwegian Bonds, we redeemed $85.2 million of the Convertible Bonds and recognized loss on partial redemption of the Convertible Bonds of $0.8 million.
Golar Tundra Facility
In December 2021, we terminated the sale and leaseback arrangement in relation to the Golar Tundra with CMBL and concurrently the Golar Tundra debt facility of $78.2 million was extinguished. We subsequently entered into a secured loan facility for $182.0 million. The Golar Tundra facility bore interest at LIBOR plus a margin of 3% and is repayable over a term of five years. As of December 31, 2021, we had drawn $158.0 million of the available funds. Subsequent drawdown is dependent upon certain charter requirements. A commitment fee is chargeable on any undrawn portion of this facility.
Revolving Credit Facility (“RCF”)
In December 2020, we entered into a $100.0 million RCF which bore interest at LIBOR plus a margin of 5% and was secured by a pledge against our shares in Hygo. The facility has a term of 366 days with two 366-day extension options available at the lenders’ discretion. In April 2021, in connection with the closing of the Hygo Merger, certain amendments to the facility were executed. While most of the existing terms remain substantially unchanged, the key amendments include: (i) changes to the security, with the release of the Hygo shares and the replacement with a pledge against Golar’s holding in 18,627,451 NFE Shares, although, if certain requirements are met, the facility allows for the release of a portion of the NFE Shares based on a prescribed loan to value ratio; and (ii) a decrease to the interest rate to LIBOR plus a margin of 4.5%. In November 2021, we repaid our $100.0 million RCF, using the proceeds from the Norwegian Bonds. The NFE Shares held as security to the RCF were subsequently released.
Corporate RCF
In November 2021 we executed the Corporate RCF, which has a term of three years, a revolving facility with a limit of $200.0 million and bears interest at LIBOR plus a margin of 2.8%. The facility is secured against the 18,627,451 NFE Shares we own. We are 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. As of December 31, 2021, we had not drawn down on this facility.
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 from the commencement of commercial operations, with a final balloon payment of $350.0 million 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 commencement of commercial operations. As of December 31, 2021, we had drawn $410.0 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.
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$1.125 billion facility
In July 2013, we entered into a $1.125 billion facility which bears interest at LIBOR plus a margin of 2.10% for the K-Sure tranche of the facility and 2.75% for both the KEXIM and commercial tranche of the loan. The facility is divided into three tranches, with the following general terms:

Tranche |  | Proportion of facility | Term of loan from date of drawdown | Repayment terms
K-Sure |  | 40% | 12 years | Six-monthly installments
KEXIM |  | 40% | 12 years | Six-monthly installments
Commercial |  | 20% | 5 years | Six-monthly installments, unpaid balance to be refinanced after 5 years

The K-Sure tranche is funded by a consortium of lenders, of which 95% is guaranteed by a Korean Trade Insurance Corporation (or K-Sure) policy; the KEXIM tranche is funded by the Export Import Bank of Korea (or KEXIM). Repayments under the K-Sure and KEXIM tranches are due semi-annually with a 12-year repayment profile. The commercial tranche is funded by a syndicate of banks and is for a term of five years from date of drawdown with a final balloon payment depending on drawdown dates for each respective vessel. In the event the commercial tranche is not refinanced prior to the end of the five years, both K-Sure and KEXIM have an option to demand repayment of the balances outstanding under their respective tranches. In October 2018, the term of the commercial tranche, and consequently the option to K-Sure and KEXIM, was extended by 5 years to 2024. The facility is further divided into vessel-specific tranches dependent upon delivery and drawdown, with each borrower being the subsidiary owning the respective vessel.
In June 2020, we refinanced the proportion of the debt facility relating to Golar Bear ahead of its maturity and the cash collateral pledged against the Golar Bear facility of $6.0 million was released. Concurrently we entered into an agreement to bareboat charter the vessel with AVIC for $110.0 million (see Lessor VIE debt below for more information). As of December 31, 2021, the remaining balance of the facility of $54.7 million relates to the Golar Frost, with a cash collateral of $0.6 million (note 15).
Lessor VIE debt
The following loans relate to our lessor VIE entities, including ICBCL, CCBFL, COSCO, CSSC and AVIC that we consolidate as variable interest entities (“VIEs”). Although we have no control over the funding arrangements of these entities, we consider ourselves the primary beneficiary of these VIEs and we are therefore required to consolidate these loan facilities into our financial results. See note 5 for additional information.

Facility | Effective from | SPV | Loan counterparty | Loan facility at inception (in $ millions) | Loan facility at December 31, 2021(in $ millions) | Loan duration/maturity | Interest
Golar Glacier | October 2014 | Hai Jiao 1401 Limited | ICBCIL Finance Co.(1) | (184.8) | (82.8) | Repayable on demand | 2.11% - 2.65%
Golar Snow | January 2015 | Hai Jiao 1402 Limited | ICBCIL Finance Co.(1) | (182.6) | (82.0) | Repayable on demand | 2.11% - 2.65%
Golar Kelvin | January 2015 | Hai Jiao 1405 Limited | ICBCIL Finance Co.(1) | (182.5) | (99.5) | Repayable on demand | 2.11% - 2.65%
Golar Ice | February 2015 | Hai Jiao 1406 Limited | ICBCIL Finance Co.(1) | (172.0) | (54.9) | Repayable on demand | 2.11% - 2.65%
Golar Seal (2) | March 2016 | Compass Shipping 1 Corporation Limited | CCBFL | (162.4) | (78.5) | 2025 | 2.46% - 3.50%
Golar Crystal | March 2017 | Oriental Fleet LNG 01 Limited | COSCO Shipping | (101.0) | (75.1) | 10 years | LIBOR plus margin
Hilli (3) | June 2018 | Fortune Lianjing Shipping S.A. | CSSC | (840.0) | (320.2) | 8 years non-recourse | LIBOR plus margin
(120.0) | (277.1) | Repayable on demand | Nil
Golar Bear | June 2020 | Cool Bear Shipping Limited | AVIC | (110.0) | (104.8) | 2023 | 3.00% - 4.00%

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The vessels in the table above are secured as collateral against these long-term loans (note 29).
(1) ICBCIL Finance Co. is a related party of ICBCL.
(2) The Golar Seal facility includes a put option that if exercised requires us to repay the facility if an appropriate long-term charter of 4 years or more is not entered into by January 2021. In November 2020, we agreed and executed an extension with CCBFL to extend such put option by one year. In November 2021, we entered into another supplemental agreement with existing lender to extend further the put option maturity from January 2025. Since then, we presented the maturity of the loan facility to January 2025 even though the maturity of the sale and leaseback arrangement is in March 2026 given the maturity date of the call option is the earlier of the two.
(3) 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 the internal loan with CSSC. 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 CSSC.
Debt restrictions
Certain of our debts are collateralized by vessel liens and, in the case of some debt, pledges of shares by each guarantor subsidiary. 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, engage in mergers and acquisitions, purchase and sell vessels, enter into time or consecutive voyage charters or distribute dividends in relation to the term loan facility. 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. In addition, as of December 31, 2021 there are cross default provisions in certain of our and Hygo's loan and lease agreements. In addition to lien security, some of our debt is also collateralized through pledges of equity shares by our guarantor subsidiaries.
As of December 31, 2021, we were in compliance with all our covenants under our various loan agreements.

22. | ACCRUED EXPENSES

(in thousands of $) | 2021 |  | 2020
Interest expense | (66,726) |  |  | (52,600) |
Administrative expenses | (12,463) |  |  | (13,078) |
Vessel operating and drydocking expenses | (12,378) |  |  | (23,334) |
Current tax payable | (1,288) |  |  | (345) |
| (92,855) |  |  | (89,357) |

Vessel operating and drydocking expense related accruals comprised of vessel operating expenses such as crew wages, vessel supplies, routine repairs, maintenance, drydocking, lubricating oils and insurances.
Administrative expenses related accruals comprised of general overhead including personnel costs, legal and professional fees, costs associated with project development, property costs and other general expenses.
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23. | OTHER CURRENT LIABILITIES

(in thousands of $) | 2021 |  | 2020
Liability for UK tax leases (note 29) | (71,739) |  |  | — |
Day 1 gain deferred revenue - current portion (1) (note 24) | (38,242) |  |  | (9,950) |
Deferred operating cost and charterhire revenue | (17,486) |  |  | (12,330) |
Mark-to-market interest rate swaps valuation (note 27) | (17,300) |  |  | (44,315) |
Current portion of operating lease liability (note 13) | (3,838) |  |  | (5,005) |
Mark-to-market foreign exchange swaps valuation (note 27) | — |  |  | (1,310) |
Other (2) | (1,775) |  |  | (12,509) |
| (150,380) |  |  | (85,419) |

(1) “Day 1 gain deferred revenue - current portion” refers to the liability upon recognition of the oil derivative embedded in the Hilli LTA of $10.0 million and the gas derivative indexed to the TTF of $28.3 million which arises from the 2022 contracted capacity of the Hilli LTA.
(2) Included in “Other” is dividend payable for lessor VIE of $nil and $7.5 million at December 31, 2021 and 2020, respectively.

24. | OTHER NON-CURRENT LIABILITIES

(in thousands of $) | 2021 |  | 2020
Day 1 gain deferred revenue (1) | (34,221) |  |  | (43,934) |
Pension obligations (note 25) | (31,357) |  |  | (37,258) |
Deferred commissioning period revenue (2) | (14,515) |  |  | (18,635) |
Non-current portion of operating lease liabilities (note 13) | (7,591) |  |  | (10,634) |
Guarantees issued to Golar Partners and Hygo (notes 14 and 28) | — |  |  | (19,545) |
Other (3) | (17,253) |  |  | (5,433) |
| (104,937) |  |  | (135,439) |

(1) This represents the corresponding liability upon recognition of the LTA derivative asset. This deferred gain is amortized and recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli. The initial amount recognized was $79.6 million, of which $34.2 million is non-current at December 31, 2021. The current portion of the Day 1 gain deferred revenue is included in “Other current liabilities” (note 23).
(2) This represents customer billing during the commissioning period, prior to vessel acceptance and commencement of the contract term, which is considered an upfront payment for services. These amounts billed are recognized as part of “Liquefaction services revenue” in the consolidated statements of operations evenly over the LTA contract term, with this commencing on the customer's acceptance of the Hilli. The initial amount recognized was $33.8 million, of which $14.5 million is non-current at December 31, 2021. The current portion of Deferred commissioning period billing is included in “Other current liabilities” (note 23).
(3) Included in “Other” are (i) an asset retirement obligation of $5.3 million and $5.0 million for the years ended December 31, 2021 and 2020, respectively. The corresponding asset of $4.7 million is recorded within vessels and equipment, net (note 19); and (ii) dividend payable for lessor VIE of $11.5 million and $nil at December 31, 2021 and 2020, respectively.

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, 2021, 2020 and 2019 was $2.2 million, $2.1 million and $2.4 million, respectively.
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Defined benefit schemes
We have two defined benefit pension plans both of which are closed to new entrants but still cover certain of our employees. Benefits are based on the employee's years of service and compensation. Net periodic pension plan costs are determined using the Projected Unit Credit Cost method. Our plans are funded by us in conformity with the funding requirements of the applicable government regulations. Plan assets consist of both fixed income and equity funds managed by professional fund managers.
We use December 31 as a measurement date for our pension plans.
The components of net periodic benefit costs are as follows:

(in thousands of $) | 2021 |  | 2020 |  | 2019
Service cost | (120) |  |  | (155) |  |  | (162) |
Interest cost | (879) |  |  | (1,271) |  |  | (1,740) |
Expected return on plan assets | 214 |  |  | 318 |  |  | 375 |
Recognized actuarial loss | (1,131) |  |  | (848) |  |  | (777) |
Net periodic benefit cost | (1,916) |  |  | (1,956) |  |  | (2,304) |

The components of net periodic benefit costs are recognized in the income statement 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, 2021 is $1.1 million (2020: $0.8 million).
The change in projected benefit obligation and plan assets and reconciliation of funded status as of December 31 are as follows:

(in thousands of $) | 2021 |  | 2020
Reconciliation of benefit obligation: |  |  |
Benefit obligation at January 1 | 54,122 |  |  | 49,943 |
Service cost | 120 |  |  | 155 |
Interest cost | 879 |  |  | 1,271 |
Actuarial (gain)/loss (1) | (4,081) |  |  | 5,458 |
Foreign currency exchange rate changes | (120) |  |  | 372 |
Benefit payments | (3,705) |  |  | (3,077) |
Benefit obligation at December 31 | 47,215 |  |  | 54,122 |

(1) Actuarial (gain)/loss 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, 2021 and 2020 was $46.7 million and $53.4 million, respectively.

(in thousands of $) | 2021 |  | 2020
Reconciliation of fair value of plan assets: |  |  |
Fair value of plan assets at January 1 | 16,864 |  |  | 15,223 |
Actual return on plan assets | (46) |  |  | 1,355 |
Employer contributions | 2,900 |  |  | 2,900 |
Foreign currency exchange rate changes | (155) |  |  | 463 |
Benefit payments | (3,705) |  |  | (3,077) |
Fair value of plan assets at December 31 | 15,858 |  |  | 16,864 |

The amounts recognized in accumulated other comprehensive income, as of December 31, 2021 and 2020, is $10.9 million and $15.9 million, respectively.
The actuarial loss recognized in other comprehensive income/(loss) is net of tax of $0.7 million, $0.6 million, and $0.5 million for the years ended December 31, 2021, 2020 and 2019, respectively.
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Employer contributions and benefits paid under the pension plans include $2.9 million paid from employer assets for the years ended December 31, 2021 and 2020.
(1) Our defined benefit pension plan comprises of two schemes as follows:

| December 31, 2021 |  | December 31, 2020
(in thousands of $) | UK Scheme |  | Marine Scheme |  | Total |  | UK Scheme |  | Marine Scheme |  | Total
Fair value of benefit obligation | (11,608) |  |  | (35,607) |  |  | (47,215) |  |  | (12,727) |  |  | (41,395) |  |  | (54,122) |
Fair value of plan assets | 15,077 |  |  | 781 |  |  | 15,858 |  |  | 15,822 |  |  | 1,042 |  |  | 16,864 |
Funded (unfunded) status at end of year | 3,469 |  |  | (34,826) |  |  | (31,357) |  |  | 3,095 |  |  | (40,353) |  |  | (37,258) |

The fair value of our plan assets, by category, as of December 31, 2021 and 2020 are as follows:

(in thousands of $) | 2021 |  | 2020
Equity securities | 15,077 |  |  | 15,822 |
Cash | 781 |  |  | 1,042 |
| 15,858 |  |  | 16,864 |

The asset allocation for our Marine scheme at December 31, 2021 and 2020, by asset category are as follows:

Marine scheme |  |  | 2021 (%) |  | 2020 (%)
Cash |  |  | 100 |  |  | 100 |
Total |  |  | 100 |  |  | 100 |

The asset allocation for our UK scheme at December 31, 2021 and 2020, by asset category are as follows:

UK scheme |  |  | 2021 (%) |  | 2020 (%)
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, 2022, 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
2022 | 380 |  |  | 2,600 |
2023 | 390 |  |  | 2,500 |
2024 | 430 |  |  | 2,400 |
2025 | 540 |  |  | 2,300 |
2026 | 430 |  |  | 2,200 |
2027 - 2031 | 2,460 |  |  | 9,500 |

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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:

| 2021 |  | 2020
Discount rate | 2.43 | % |  | 1.68 | %
Rate of compensation increase | 2.70 | % |  | 2.29 | %

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:

| 2021 |  | 2020
Discount rate | 2.44 | % |  | 1.69 | %
Expected return on plan assets | 1.31 | % |  | 2.06 | %
Rate of compensation increase | 2.75 | % |  | 2.31 | %

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, 2021 and 2020 is based on the weighted average of various returns on assets using the asset allocation as at the beginning of 2021 and 2020. For equities and other asset classes, we have applied an equity risk premium over ten-year governmental bonds.

26. | SHARE CAPITAL AND SHARE BASED COMPENSATION

Our common shares are listed on the Nasdaq Stock Exchange.
As at December 31, 2021 and 2020, our authorized and issued share capital is as follows:
Authorized share capital:

(in thousands of $, except per share data) | 2021 |  | 2020
150,000,000 (2020: 150,000,000) common shares of $1.00 each | 150,000 |  |  | 150,000 |

Issued share capital:

(in thousands of $, except per share data) | 2021 |  | 2020
108,222,604 (2020: 109,943,594) outstanding issued common shares of $1.00 each | 108,223 |  |  | 109,944 |

(number of shares) | 2021 |  | 2020
As at January 1 | 109,943,594 |  |  | 101,302,404 |
Repurchase and cancellation of treasury shares (1) | (1,984,647) |  |  | (3,500,000) |
Issuance of shares (2) | — |  |  | 12,067,789 |
Vesting of RSUs | 263,657 |  |  | 73,401 |
As at December 31 | 108,222,604 |  |  | 109,943,594 |

(1) During 2021, we repurchased and cancelled 2.0 million of treasury shares for a consideration of $24.5 million inclusive of brokers commission of $0.04 million.
In February 2020, we purchased 1.5 million shares for a consideration of $70.4 million and cancelled all our 3.5 million treasury shares, that we repurchased in 2020 and prior years.
(2) In December 2020, we closed a registered equity offering of 12,067,789 of our common shares, at par value of $1.00 per share. We raised proceeds, net of the underwriter's discount and offering fees, of approximately $100 million, which we used to partially repay the term loan facility, fully repay the margin loan facility and for general corporate purposes.
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Contributed surplus
As at December 31, 2021 and 2020 we had contributed surplus of $200 million. Contributed surplus is capital that can be returned to stockholders without the need to reduce share capital, thereby giving Golar greater flexibility when it comes to declaring dividends.
Share options
The Golar LNG Limited Long Term Incentive Plan (“LTIP”) was adopted by our board of directors, effective as of October 24, 2017. The maximum aggregate number of common shares that may be delivered pursuant to any and all awards under the Company’s LTIP shall not exceed 3,000,000 common shares, subject to adjustment due to recapitalization or reorganization as provided under the LTIP. The LTIP allows for grants of (i) share options, (ii) share appreciation rights, (iii) restricted share awards (iv) share awards, (v) other share-based awards, (vi) cash awards, (vii) dividend equivalent rights, (viii) substitute awards and (ix) performance-based awards, or any combination of the foregoing as determined by the board of directors or nominated committee in its sole discretion. Either authorized unissued shares or treasury shares (if there are any) in the Company may be used to satisfy exercised options.
In 2021, the Company granted 750,000 share options to its officers. The options vest in equal installments over 2 years and have a three-year term. In 2020, no share options were awarded to employees.
The fair value of each option award is estimated on the grant date or modification date using the Black-Scholes option pricing model. The weighted average assumptions as at 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 stock.
Where the criteria for using the simplified method are met, we have used this method to estimate the expected term of options based on the vesting period of the award that represents the period 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 at December 31, 2021, 2020 and 2019, the number of options outstanding in respect of Golar shares was 1.5 million, 1.8 million and 2.7 million, respectively.
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A summary of the share option activity for the year ended December 31, 2021 is presented below:

| Shares (in '000s) |  | Weighted average exercise price |  | Weighted average remaining contractual term (years)
Options outstanding at December 31, 2020 | 1,841 |  |  | $ | 24.62 |  |  | 1.2
Granted during the year | 750 |  |  | $ | 10.97 |  |  |
Forfeited during the year | (205) |  |  | $ | 23.46 |  |  |
Lapsed during the year | (881) |  |  | $ | 25.19 |  |  |
Options outstanding at December 31, 2021 | 1,505 |  |  | $ | 17.65 |  |  | 1.6

Options outstanding and exercisable at: |  |  |  |  |
December 31, 2021 | 755 |  |  | $ | 24.28 |  |  | 0.8
December 31, 2020 | 1,717 |  |  | $ | 24.46 |  |  | 1.2
December 31, 2019 | 2,221 |  |  | $ | 30.74 |  |  | 1.7

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, 2021, 2020 and 2019, 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 $) | 2021 |  | 2020 |  | 2019
Total fair value of share options fully vested in the year | 1,595 |  |  | 3,175 |  |  | 8,967 |
Compensation cost recognized in the consolidated statement of income | 1,434 |  |  | 2,274 |  |  | 7,148 |
Share options cost capitalized* | 16 |  |  | 110 |  |  | 608 |

*Relates to capitalized costs on share options awarded to employees directly involved in certain vessel conversion projects.
As of December 31, 2021, the total unrecognized compensation cost amounting to $1.8 million relating to options outstanding is expected to be recognized over a weighted average period of 1.4 years.
Restricted Stock Units (RSU)
Time-based RSUs
Pursuant to the LTIP, the Company granted certain individuals nil and 0.7 million of RSUs during the years ended December 31, 2021 and 2020, respectively. The RSUs vest equally over a period of 3 years.
The fair value of the RSU award is estimated using the market price of our common stock at grant date with expense recognized over the three-year vesting period.
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A summary of time-based RSU activities for the year ended December 31, 2021 is presented below:

| Shares (in '000s) |  | Weighted average grant date fair value per share |  | Weighted average remaining contractual term (years)
Non-vested RSUs at December 31, 2020 | 748 |  |  | 10.02 |  | 2.0
Vested during the year | (264) |  |  | 10.94 |  |
Forfeited during the year | (141) |  |  | 9.07 |  |
Non-vested RSUs at December 31, 2021 | 343 |  |  | 9.71 |  | 1.1

Performance-based RSUs
In March 2020, the Company also granted certain individuals RSUs that are 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 ending 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 the Company’s 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 fee 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 stock 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, 2021 is presented below:

| Shares (in '000s) |  | Weighted average grant date fair value per share |  | Weighted average remaining contractual term (years)
Non-vested performance based RSUs at December 31, 2020 | 159 |  |  | 6.25 |  | 2.21
Forfeited during the year | (131) |  |  | 6.25 |  |
Non-vested performance based RSUs at December 31, 2021 | 28 |  |  | 6.25 |  | 1.21

| Year ended December 31
(in thousands of $) | 2021 |  | 2020 |  | 2019
Compensation cost recognized in the consolidated statement of income | 1,774 |  |  | 2,739 |  |  | 1,124 |
RSU cost capitalized* | 322 |  |  | 295 |  |  | — |

*Relates to capitalized costs on RSUs awarded to employees directly involved in certain vessel conversion projects.
As of December 31, 2021, the total unrecognized compensation cost of $1.7 million relating to both time-based and performance based RSUs outstanding is expected to be recognized over a weighted average period of 1.0 year.
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27. | FINANCIAL INSTRUMENTS

Interest rate risk management
In certain situations, we may enter into financial instruments to reduce the risk associated with fluctuations in interest rates. We have entered into swaps that convert floating rate interest obligations to fixed rates, which from an economic perspective, hedge the interest rate exposure. We do not hold or issue instruments for speculative or trading purposes. The counterparties to such contracts are major banking and financial institutions. Credit risk exists to the extent that the counterparties are unable to perform under the contracts; however we do not anticipate non-performance by any of our counterparties.
We manage our debt portfolio with interest rate swap agreements in U.S. dollars to achieve an overall desired position of fixed and floating interest rates. Since 2015, we have ceased hedge accounting for any of our derivatives.
As of December 31, 2021 and 2020, we were party to the following interest rate swap transactions involving the payment of fixed rates in exchange for LIBOR as summarized below:

Instrument (in thousands of $) |  | Year end |  | Notional value |  | Maturity dates |  | Fixed interest rates
Interest rate swaps: |  |  |  |  |  |  |  |
Receiving floating, pay fixed |  | 2021 |  | 505,000 |  |  | 2024/2029 |  | 1.69% to 2.37%
Receiving floating, pay fixed |  | 2020 |  | 597,500 |  |  | 2021/2029 |  | 1.69% to 2.37%

Foreign currency risk
The majority of the vessels' gross earnings are receivable in U.S. dollars. The majority of our transactions, assets and liabilities are denominated in U.S. dollars, our functional currency. However, we incur 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
A derivative asset, representing the fair value of the estimated discounted cash flows of payments due as a result of the Brent Crude price moving above the contractual floor of $60.00 per barrel over the contract term, was recognized in December 2017 following the effectiveness of the LTA. Golar bears no downside risk should the Brent Crude price move below $60.00.
The 2022 Incremental Capacity for the Hilli is linked to European natural gas prices. During the year ended December 31, 2021, we were party to a commodity swap involving the payment of fixed prices in exchange for Dutch Natural Gas to manage our exposure to the European natural gas prices as summarized below:

Instrument |  | Year end |  | Notional quantity (tons) |  | Maturity date |  | Fixed price
Commodity swap derivatives: |  |  |  |  |  |  |  |
Receiving fixed, pay floating |  | 2021 |  | 23,249 |  |  | 2022 |  | $23.25 to $28.00

Equity price risk
Our Board of Directors has approved a share repurchase program, which is being partly financed through the use of total return swap or equity swap facilities with third party banks, indexed to our own shares. We carry the risk of fluctuations in the share price of those acquired shares. The banks are compensated at their cost of funding p lus a margin. In February 2020, we purchased the remaining 1.5 million of our shares and 107,000 of Golar Partners' 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 restricted cash was released at repurchase, with $55.5 million to settle the derivative liability fair value (note 15) 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 at December 31, 2020 was a loss of $5.1 million.
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Fair values of financial instruments
We recognize our fair value estimates using a fair value hierarchy based on the inputs used to measure fair value. The fair value hierarchy has three levels based on reliability of inputs used to determine fair value as follows:
Level 1: Quoted market prices in active markets for identical assets and liabilities;
Level 2: Observable market-based inputs or unobservable inputs that are corroborated by market data; and
Level 3: Unobservable inputs that are not corroborated by market data.
There have been no transfers between different levels in the fair value hierarchy during the year.
The carrying value and fair value of our financial instruments at December 31, 2021 and 2020 are as follows:

|  | 2021 | 2021 | 2020 | 2020
(in thousands of $) | Fair value hierarchy | Carrying value | Fair value | Carrying value | Fair value
Non-derivatives: |  |  |  |  |
Cash and cash equivalents (1) | Level 1 | 268,627 |  | 268,627 |  | 127,691 |  | 127,691 |
Restricted cash and short-term deposits (2) | Level 1 | 150,165 |  | 150,165 |  | 163,181 |  | 163,181 |
Trade accounts receivable (3) | Level 1 | 29,749 |  | 29,749 |  | 29,648 |  | 29,648 |
Investment in listed equity securities (4) | Level 1 | 449,666 |  | 449,666 |  | — |  | — |
Trade accounts payable (3) | Level 1 | (12,405) |  | (12,405) |  | (10,579) |  | (10,579) |
Current portion of long-term debt and short-term debt (5) (6) (7) | Level 2 | (736,905) |  | (736,905) |  | (984,510) |  | (984,510) |
Current portion of convertible bonds (6) (8) | Level 2 | (315,646) |  | (316,561) |  | — |  | — |
Long-term debt – convertible bonds (6) (8) | Level 2 | — |  | — |  | (383,740) |  | (366,581) |
Long-term debt (6) (7) | Level 2 | (1,389,374) |  | (1,389,374) |  | (1,011,281) |  | (1,011,281) |
Derivatives: |  |  |  |  |
Oil and gas derivative instruments (9) (10) | Level 2 | 207,058 |  | 207,058 |  | 540 |  | 540 |
Interest rate swaps liability (9) (11) (12) (13) | Level 2 | (17,300) |  | (17,300) |  | (44,315) |  | (44,315) |
Commodity swap asset (11) | Level 2 | 1,753 |  | 1,753 |  | — |  | — |
Commodity swap liability (11) | Level 2 | (88) |  | (88) |  | — |  | — |
Foreign exchange swaps liability (9) (11) (13) | Level 2 | — |  | — |  | (1,310) |  | (1,310) |

(1) The carrying value of cash and cash equivalents, which are highly liquid, is a reasonable estimate of fair value.
(2) The carrying value of restricted cash and short-term deposits is considered to be equal to the estimated fair value because of their near term maturity.
(3) The carrying values of trade accounts receivable and trade accounts payable approximate fair values because of the near term maturity of these instruments.
(4) “Investment in listed equity securities” refers to our 18.6 million NFE Shares (note 14 and 16). The fair value was calculated using the NFE closing share price as at December 31, 2021, resulting in a valuation of $449.7 million.
(5) The carrying amounts of our short-term debt approximate their fair values because of the near term maturity of these instruments.
(6) 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 32.1 million and $28.7 million at December 31, 2021 and December 31, 2020, respectively.
(7) The estimated fair values for both the floating long-term debt and short-term debt to a related party are considered to be equal to the carrying value since they bear variable interest rates, which are adjusted on a quarterly or six-monthly basis.
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(8) The estimated fair value for the liability component of the unsecured convertible bonds is based on the quoted market price as at the balance sheet date.
(9) Derivative assets are generally captured within other current assets and non-current assets and derivative liabilities are captured within other current liabilities on the balance sheet.
(10) The fair value of the oil and gas derivative instruments was determined using the estimated discounted cash flows of the additional payments due to us as a result of oil prices moving above a contractual oil price floor over the term of the LTA and the estimated discounted cash flows of the additional payments due to us in 2022 as a result of gas prices moving with respect to the contractual pricing terms per the LTA Amendment and the Euro/USD exchange rates based on the forex forward curve. Significant inputs used in the valuation of the oil and gas derivative instruments include 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.
(11) 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.
(12) The credit exposure of interest rate swap agreements is represented by the fair value of contracts with a positive value at the end of each period, reduced by the effects of master netting arrangements. It is our policy to enter into master netting agreements with counterparties to derivative financial instrument contracts, which give us the legal right to discharge all or a portion of the amounts owed to the counterparty by offsetting them against amounts that the counterparty owes to us.
(13) The fair value measurement of a liability must reflect the non-performance of the entity. Therefore, the impact of our credit worthiness has also been factored into the fair value measurement of the derivative instruments in a liability position.
The following methods and assumptions were used to estimate the fair value of our other classes of financial instrument:
•The carrying values of loans 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, 2021 and 2020:

| Balance sheet classification | 2021 |  | 2020
(in thousands of $) |  |  |  |
Asset derivatives |  |  |  |
Gas derivative instrument | Other current assets (note 16) | 79,578 |  |  | — |
Oil derivative instrument | Other non-current assets (note 20) | 127,480 |  |  | 540 |
Commodity swap | Other current assets (note 16) | 1,753 |  |  | — |
Total asset derivatives |  | 208,811 |  |  | 540 |
Liability derivatives |  |  |  |
Interest rate swaps | Other current liabilities (note 23) | (17,300) |  |  | (44,315) |
Commodity swap | Other current liabilities (note 23) | (88) |  |  | — |
Foreign exchange swaps | Other current liabilities | — |  |  | (1,310) |
Total liability derivatives |  | (17,388) |  |  | (45,625) |

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It is our policy to enter into master netting agreements with the counterparties to derivative financial instrument contracts, which give us the legal right to discharge all or a portion of amounts owed to the counterparty by offsetting them against amounts that the counterparty owes to us. We have elected not to offset the fair values of derivative assets and liabilities executed with the same counterparty that are generally subject to enforceable master netting arrangements. As of December 31, 2021 and 2020, the amounts presented in our consolidated balance sheet in relation to interest rate swaps and foreign exchange swaps are not able to be 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, 2021 and 2020 would be adjusted as detailed in the following table:

| 2021 | 2020
| 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 | 1,753 |  | (88) |  | 1,665 |  | — |  | — |  | — |
Total liability derivatives | (88) |  | 88 |  | — |  | — |  | — |  | — |

Some of our interest rate swaps have a credit arrangement that requires us to provide cash collateral when the market value of the instrument falls below a specified threshold. As of December 31, 2021 and December 31, 2020, cash collateral amounting to $nil and $8.9 million has been provided (note 15).
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 Internationale Nederlanden Groep (“ING”) Bank, Nordea Bank ABP, DNB Bank ASA, Citibank, Standard Chartered and Danske Bank. However, we believe this risk is remote, as they are established and reputable establishments with no prior history of default.
There is a concentration of financing risk with respect to our long-term debt to the extent that a substantial amount of our long-term debt is carried with ING, Citibank, Nordea Bank, Danske Bank A/S, DNB Bank ASA, K-Sure, KEXIM and commercial lenders of our $1.125 billion facility, as well as with ICBCL, CCBFL, COSCO, CSSC and AVIC in regards to our sale and leaseback arrangements (note 5). We believe these counterparties to be sound financial institutions, with investment grade credit ratings. Therefore, we believe this risk is remote.
We also have an equity investment in our affiliate, Avenir, as of December 31, 2021, our ownership interests and the carrying value of the investment recorded in our balance sheet as of December 31, 2021 was 23.5% and $47.9 million, respectively. Accordingly, the value of our investment and the income generated from Avenir is subject to specific risks associated with its business. In the event the decline in the fair value of the investment falls below the carrying value and it was determined to be other-than-temporary, we would be required to recognize an impairment loss.
A further concentration of supplier risk exists in relation to the Gimi undergoing FLNG conversion with Keppel and B&V. However, we believe this risk is remote as Keppel are global leaders in the shipbuilding and vessel conversion sectors while B&V is a global engineering, procurement and construction company.
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28. | RELATED PARTY TRANSACTIONS

a) Transactions with existing related parties:
Net revenues/(expenses): The transactions with other related parties for the years ended December 31, 2021, 2020 and 2019 consisted of the following:

(in thousands of $) | 2021 |  | 2020 |  | 2019
ECGS (1) | 1,482 |  |  | — |  |  | — |
Avenir LNG (2) | 468 |  |  | 980 |  |  | — |
Borr Drilling (3) | 348 |  |  | 384 |  |  | 542 |
2020 Bulkers (4) | 111 |  |  | 45 |  |  | 265 |
Magni Partners (5) | (189) |  |  | (606) |  |  | (858) |
The Cool Pool (6) | — |  |  | — |  |  | 39,666 |
Total | 2,220 |  |  | 803 |  |  | 39,615 |

Receivables: The balances with other related parties as of December 31, 2021 and 2020 consisted of the following:

(in thousands of $) | 2021 | 2020
Avenir LNG (2) | 3,225 |  | 980 |
Borr Drilling (3) | 149 |  | 936 |
Magni Partners (5) | 81 |  | 81 |
2020 Bulkers (4) | 29 |  | 51 |
Total | 3,484 |  | 2,048 |

(1) We chartered Golar Ice to ECGS during the year ended December 31, 2021.
(2) Avenir LNG entered into agreements to compensate Golar in relation to the provision of certain debt guarantees relating to Avenir LNG and its subsidiaries. This compensation amounted to an aggregate of $0.5 million, $1.0 million and $nil for the years ended December 31, 2021, 2020 and 2019, respectively. In October 2021, we provided a one year revolving shareholder loan of $5.3 million to Avenir, of which $1.8 million was drawn as of December 31, 2021. The facility bears a fixed interest rate of 5% per annum. As of December 31, 2021, we have an interest receivable and commitment fee receivable on the undrawn portion of the loan of $15.3 thousand and $12.3 thousand, respectively.
(3) Borr Drilling - Tor Olav Trøim is the founder, and director of Borr Drilling, a Bermuda company listed on the Oslo and NASDAQ stock exchanges. Receivables comprise primarily of management and administrative services provided by our Bermuda corporate office.
(4) 2020 Bulkers is a related party by virtue of common directorships. Receivables comprise primarily of management and administrative services provided by our Bermuda corporate office.
(5) Magni Partners - Tor Olav Trøim is the founder of, and partner in, Magni Partners (Bermuda) Limited, 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.
(6) The Cool Pool - On July 8, 2019 GasLog's vessel charter contracts had concluded and withdrew their participation from the Cool Pool. Following GasLog's departure, we assumed sole responsibility for the management of the Cool Pool and consolidate the Cool Pool. From the point of consolidation, the Cool Pool ceased to be a related party.
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The table below summarizes our net earnings (impacting each line item in our consolidated statement of operation) generated from our participation in the Cool Pool:

(in thousands of $) | 2019
Time and voyage charter revenues | 43,332 |
Time charter revenues - collaborative arrangement | 23,359 |
Voyage, charterhire expenses and commission expenses | (8,092) |
Voyage, charterhire and commission expenses - collaborative arrangement | (18,933) |
Net income from the Cool Pool | 39,666 |

b) Transactions with former related parties
b.1) Golar Partners and subsidiaries:
Following the completion of the GMLP Merger on April 15, 2021, Golar Partners ceased to be a related party and subsequent transactions with Golar Partners and its subsidiaries are treated as a third party and settled under normal payment terms. 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).
Net revenues: The transactions with Golar Partners and its subsidiaries for the period from January 1, 2021 to April 15, 2021 and for the years ended December 31, 2020 and 2019 consisted of the following:

(in thousands of $) | Period ended April 15, 2021 | Year Ended December 31, 2020 | Year Ended December 31, 2019
Management and administrative services revenue (1) | 1,717 |  | 7,941 |  | 9,645 |
Ship management fees revenue (2) | 2,251 |  | 5,263 |  | 4,460 |
Interest income on short-term loan (3) | 18 |  | 317 |  | 109 |
Total | 3,986 |  | 13,521 |  | 14,214 |

Receivables (payables): The balances with Golar Partners and subsidiaries as of December 31, 2021 and 2020 consisted of the following:

(in thousands of $) | 2021 | 2020
Balances due to Golar Partners and its subsidiaries (3) | — |  | (1,133) |
Methane Princess lease security deposit movements (4) | — |  | 349 |
Total | — |  | (784) |

(1) Management and administrative services revenue - On March 30, 2011, Golar Partners entered into a management and administrative services agreement with Golar Management Limited (“Golar Management”), a wholly-owned subsidiary of Golar, pursuant to which Golar Management will provide to Golar Partners certain management and administrative services. The services provided by Golar Management are charged at cost plus a management fee equal to 5% of Golar Management’s costs and expenses incurred in connection with providing these services. Golar Partners may terminate the agreement by providing 120 days written notice.
(2) Ship management fees - Golar and certain of its affiliates charge ship management fees to Golar Partners for the provision of technical and commercial management of Golar Partners' vessels. Each of Golar Partners’ vessels is subject to management agreements pursuant to which certain commercial and technical management services are provided by Golar Management. Golar Partners may terminate these agreements by providing 30 days written notice.
(3) Interest income on short-term loan, balances due(to)/from Golar Partners and its subsidiaries - Receivables and payables with Golar Partners and its subsidiaries are comprised primarily of unpaid management fees and expenses for management, advisory and administrative services, dividends in respect of the Hilli Common Units and other related party arrangements including the short term loan and Hilli disposal. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Balances owing to or due from Golar Partners and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business.
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During the year ended December 31, 2020, we loaned a total of $45.0 million with interest of LIBOR plus a margin of 5.0% to Golar Partners. The loan was fully repaid, including interest of $0.3 million during the year ended December 31, 2020.
In November 2019, we loaned $15.0 million to Golar Partners, with interest of LIBOR plus 5.0%. The loan was fully repaid, including interest of $0.1 million, in December 2019.
(4) Methane Princess lease security deposit movements - This represents net advances from Golar Partners since its IPO, which correspond with the net release of funds from the security deposits held relating to a lease for the Methane Princess. This is in connection with the Methane Princess tax lease indemnity provided to Golar Partners under the predecessor Omnibus Agreement which terminated on April 15, 2021.
Under the predecessor omnibus agreement, we provided a $11.4 million tax indemnification guarantee to Golar Partners in connection with the Methane Princess finance lease which was voluntarily terminated contemporaneously with closing of the GMLP Merger (note 29) where we paid $8.6 million and $0.8 million to the lessor and Golar Partners respectively, and released the remaining liability to the income statement (note 14).
Other transactions:
During the period ended April 15, 2021 and years ended December 2020 and 2019, we received total distributions from Golar Partners of $0.5 million, $10.5 million, and $36.8 million, respectively, with respect to common units and general partners units owned by us.
During the period ended April 15, 2021 and years ended December 2020 and 2019, Hilli LLC declared distributions totaling $7.2 million $19.4 million and $17.5 million, respectively, with respect to the common units owned by Golar Partners. We have agreed to indemnify Golar Partners for certain costs incurred in 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 Hilli distributions for the period ended April 15, 2021 and years ended December 2020 and 2019, is $0.1 million, $0.4 million and $2.2 million, respectively with respect to Hilli's indemnification cost. As of December 31, 2021, 2020 and 2019, we have a dividend payable of $nil, $nil and $4.5 million, respectively, to Golar Partners.
b.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. 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).
Net revenues: The transactions with Hygo and its subsidiaries for the period from January 1, 2021 to April 15, 2021 and for the years ended December 31, 2020 and 2019 consisted of the following:

(in thousands of $) | Period ended April 15, 2021 | Year Ended December 31, 2020 | Year Ended December 31, 2019
Management and administrative services revenue | 2,051 |  | 5,281 |  | 5,904 |
Ship management fees income | 904 |  | 1,780 |  | 1,210 |
Debt guarantee compensation (1) | 676 |  | 3,826 |  | 693 |
Other (2) | — |  | — |  | (2) |
Total | 3,631 |  | 10,887 |  | 7,805 |

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Payables: The balances with Hygo and its subsidiaries as of December 31, 2021 and 2020 consisted of the following:

(in thousands of $) | 2021 | 2020
Balances due to Hygo and subsidiaries (2) | — |  | (11,222) |

(1) Debt guarantee compensation - In connection with the closing of the Hygo and Stonepeak transaction, Hygo entered into agreements to compensate Golar in relation to certain debt guarantees (as further described under the subheading “Guarantees and other”) relating to Hygo and subsidiaries. The compensation amounted to $0.7 million, $3.8 million and $0.7 million income for the period from January 1, 2021 to April 15, 2021 and for the years ended December 31, 2020 and 2019, respectively.
(2) Balances due to Hygo and subsidiaries - Receivables and payables with Hygo and its subsidiaries are comprised primarily of unpaid management fees, advisory and administrative services. In addition, certain receivables and payables arise when we pay an invoice on behalf of a related party and vice versa. Receivables and payables are generally settled quarterly in arrears. Balances owing to or due from Hygo and its subsidiaries are unsecured, interest-free and intended to be settled in the ordinary course of business. In December 2019, we loaned $7.0 million to Hygo, with interest of LIBOR plus 5.0%. The loan was fully repaid, including interest, in December 2019.
Guarantees:
a) Debt guarantees - As described in (i) above, we receive compensation from Hygo in relation to our provision of guarantees on certain of its long term debt. In January 2020, the Golar Celsius was refinanced and we provided a debt guarantee to a third party bank in respect of the secured debt facility maturing on March 2027. We have also agreed to provide a debt guarantee on the Golar Nanook to a third party bank in respect of the secured debt facility maturing on September 2030. In December 2019, the Golar Penguin was refinanced, with a cross-default provision on the Golar Crystal. A cross-default provision means that if we or Hygo default on one loan or lease, we would then default on our other loans containing such cross-default provision. These debt facilities are secured against specific vessels. The liability which is recorded in “Other current liabilities” and “Other non-current liabilities” is being amortized over the remaining term of the respective debt facilities with the credit being recognized in “Other financial item”. These debt facilities are secured against specific vessels. As of December 31, 2020, we guaranteed $422.3 million of Hygo's gross long-term debt obligations.
Other transactions:
Net Cool Pool expenses/income - Net expenses/income relating to the other pool participants are presented in our consolidated Statement of Operation in the line item “Voyage, charter hire and commission expenses” for the period from January 1, 2021 to April 15, 2021 and for the years ended December 31, 2021 and 2020 amounted to $2.9 million and $2.1 million of net expenses and $1.6 million of net income, respectively.
b.3) OneLNG and subsidiaries:
Receivables: The balances with OneLNG and its subsidiaries as of December 31, 2021 and 2020 consisted of the following:

(in thousands of $) | 2021 | 2020
Balances due from OneLNG (1) | — |  | 64 |

(1) Balances due from OneLNG - Receivables with One LNG and its subsidiaries comprise primarily of unpaid advisory, administrative services and payment on behalf of a related party. Balances due from OneLNG are unsecured and interest free.
Subsequent to the decision to dissolve OneLNG, we have written off $0.1 million, $nil and $3.0 million of the trading balance with OneLNG for the years ended December 31, 2021, 2020 and 2019, respectively, to “Other operating income” in our consolidated statements of operations as we deem it to be no longer recoverable. During the year ended December 31, 2021, 2020 and 2019, we received $nil, $0.6 million and $4.5 million from OneLNG.
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29. | COMMITMENTS AND CONTINGENCIES

Assets pledged

(in thousands of $) | 2021 |  | 2020
Book value of vessels secured against long-term loans(1) | 2,855,168 |  |  | 2,959,535 |

(1) This excludes the Gimi which is classified as “Assets under development” (see note 18) and secured against its specific debt facility (note 20).
Corporate RCF
As at December 31, 2021, the Corporate RCF is secured by a pledge against our 18,627,451 shares in NFE. We are 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.
RCF
As at December 31, 2020, the RCF was secured by a pledge against our shares in Hygo (note 21). In April 2021, in connection with the closing of the Hygo Merger, certain amendments to the facility were executed. Whilst most of the existing terms remain substantially unchanged, the key amendments include: (i) changes to the security, with the release of the Hygo shares and the replacement with a pledge against Golar’s holding in 18,627,451 NFE Shares, although, if certain requirements are met, the facility allows for the release of a portion of the NFE Shares based on a prescribed loan to value ratio; and (ii) a decrease to the interest rate to LIBOR plus a margin of 4.5%. In November 2021, the RCF was repaid and the pledged security was released (note 21).
Capital Commitments
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 contractual commitments and contingencies
UK tax lease benefits
During 2003 we entered into six UK tax leases. Under the terms of the leasing arrangements, the benefits are derived primarily from the tax depreciation assumed to be available to the lessors as a result of their investment in the vessels. As is typical in these leasing arrangements, as the lessee we are obligated to maintain the lessor’s after-tax margin. Accordingly, in the event of any adverse tax changes or a successful challenge by the UK Tax Authorities (“HMRC”) with regard to the initial tax basis of the transactions, or in relation to the 2010 lease restructurings, or in the event of an early termination of the Methane Princess lease, we may be required to make additional payments principally to the UK vessel lessor, which could adversely affect our earnings or financial position. We would be required to return all, or a portion of, or in certain circumstances significantly more than, the upfront cash benefits that we received in respect of our lease financing transactions, including the 2010 restructurings and subsequent termination transactions. The gross cash benefit we received upfront on these leases amounted to approximately £41 million ($56.0 million) (before deduction of fees).
Of these six leases, we have since terminated five, with one lease remaining as at December 31, 2020, the Methane Princess lease. Pursuant to the deconsolidation of Golar Partners in 2012, Golar Partners is no longer considered a controlled entity but an affiliate and therefore as at December 31, 2020, the capital lease obligation relating to this remaining UK tax lease is not included on our consolidated balance sheet. However, under the indemnity provisions of the omnibus agreement or the respective share purchase agreements, we agreed to indemnify Golar Partners in the event of any tax liabilities in excess of scheduled or final scheduled amounts arising from the Methane Princess leasing arrangements and termination thereof. As of December 31, 2020, the lessor of the Methane Princess had a second priority security interest in the Methane Princess, the Golar Spirit, the Golar Grand and the Golar Tundra.
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On April 15, 2021, we completed the disposal of Golar Partners to NFE (as further discussed in note 9) and contemporaneously with completion, Golar Partners voluntarily terminated the Methane Princess lease. Therefore as at December 31, 2021, all six UK tax leases are terminated. Under the indemnity provisions of the omnibus agreement entered into with Golar Partners and the tax indemnification agreement entered into with NFE, we have agreed to indemnify NFE in the event of any further tax liabilities in excess of the final scheduled amounts arising from the Methane Princess leasing arrangements and termination thereof. With effect from April 15, 2021, the lessor for the six UK tax leases has a first priority security interest in the Golar Gandria and second priority interests in relation to the Golar Tundra, the Golar Frost and $16.0 million cash deposit which replaced the lessor’s previous security interests in the Golar Spirit, Methane Princess and the Golar Grand.
HMRC has been challenging the use of similar lease structures and has been engaged in litigation of a test case for some years. In August 2015, following an appeal to the Court of Appeal by HMRC which set aside previous judgements in favor of the taxpayer, the First Tier Tribunal (“FTT or the UK court”) ruled in favor of HMRC. The taxpayer in this particular ruling has the election to appeal the courts’ decision, but no appeal has been filed. The judgments of the FTT do not create binding precedent for other UK court decisions and therefore the ruling in favor of HMRC is not binding in the context of our structures. Further, we consider there are differences in the fact pattern and structure between this case and our 2003 leasing arrangements and therefore is not necessarily indicative of any outcome. HMRC has written to our lessor to indicate that they believe our lease may be similar to the case noted above. In December 2019, in conjunction with our lessor, Golar obtained supplementary legal advice confirming our position. Golar's discussions with HMRC on this matter concluded without agreement and, in January 2020 we received a closure notice to the inquiry stating the basis of HMRC's position. Consequently, a notice of appeal against the closure notice was submitted to HMRC. In December 2020, a notice of appeal was submitted to the FTT.
In 2021, we reopened discussions with HMRC and as at December 31, 2021, we revised our estimate of the reasonably possible loss and recorded a $71.7 million liability, net of amounts paid by our lessor to HMRC and including contingent fees payable contemporaneous with the settlement. In April 2022, we settled and paid in full our liability (note 30). Any eventual net cash outflow will be classified as a financing cash outflow given it is deemed to represent additional interest due to the lessor under the now-terminated leasing arrangements.
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, 2021, 2020 and 2019 we received loss of hire insurance income of $5.0 million for the Golar Ice, $3.3 million for the Golar Bear and Golar Ice and $4.0 million for the LNG Croatia, respectively. The above is recognized in “Other operating income” in our consolidated statement of operations.
In 2017, we commenced arbitration proceedings arising from the delays and the termination of the Golar Tundra time charter with a former charterer. For the year ended December 31, 2019, we recovered the final installment settlement of $9.3 million in charter earnings, recognized in “Other operating income” in the consolidated statements of operations.

30. | SUBSEQUENT EVENTS

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 bilateral facility
In February 2022, we executed a $250 million corporate bilateral facility with Sequoia Investment Management secured by Golar's shareholdings in FLNG Hilli and Gimi. The corporate bilateral facility has a tenor of 7-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. The corporate bilateral facility remained undrawn as of April 14, 2022 and will remain available for drawdown until 30 June 2022.
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Share buyback
In March 2022, we repurchased 368,496 of our own shares, under the s hare repurchase program, at a total cost of $6.6 million, inclusive of related fees. These shares were subsequently cancelled at March 31, 2022, reducing the balance of our issued and outstanding common shares.
Sale of NFE common stock
In April 2022, we sold 6.2 million of our NFE common stock raising net proceeds of $253.0 million. We plan to use these proceeds to deploy FLNG growth projects and general corporate purposes. Following the sale of such shares, our remaining holdings in NFE common stock is 12.4 million.
UK tax lease benefits
In April 2022, we settled and paid in full with the UK HMRC our liability in relation to past tax leases, amounting to $63.5 million, of which $16.0 million was funded from our restricted cash. The first priority security interest on the Gandria and the second priority security interests on the Golar Tundra and Golar Frost were also released.
Disposal of Cool Co and subsidiaries
On January 26, 2022, we and Cool Co, our wholly owned subsidiary, entered into a share purchase agreement (“the Vessel SPA”) under which Cool Co will acquire eight modern TFDE LNG vessels and the Cool Pool Limited, the fleet’s commercial management company (“the Disposal Group”), from us. The purchase price for each vessel was agreed at $145.0 million, subject to working capital and debt adjustments. Following completion of the Vessel SPA in April 2022, we now own a 31.3% interest in Cool Co. The existing sale and leaseback loans, except for the loans secured over the Golar Ice and the Golar Kelvin which will be assumed by Cool Co, were refinanced in connection with the closing of the Vessel SPA and were contemporaneously deconsolidated from our financial statements. Post completion of the Vessel SPA, we will continue to be the guarantor to the Golar Ice and the Golar Kelvin sale and leaseback arrangements. Subject to certain adjustments which include but are not limited to net debt and working capital at the date of deconsolidation, the indicative loss on disposal is estimated at $200 - $250 million. Of the minimum contractual future revenue receivable from our existing charterers and the minimum contractual future expense payable to our existing lessors (note 13) as at December 31, 2021, $294.2 million and $2.4 million, respectively are associated to the eight TFDE vessels which we subsequently sold to Cool Co in March and April 2022.
Although we announced in December 2021 the execution of a pre-commitment agreement to separate our eight TFDE LNG vessels into Cool Company Ltd, the consummation of the pre-commitment agreement was subject to the receipt of certain approvals and third-party consents, successful raise of equity and the satisfaction of other customary closing conditions. As such we have concluded that the Disposal Group did not meet the definition of held for sale and discontinued operations as at December 31, 2021.
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The table below provides the proforma balance sheet assuming the deconsolidation of Cool Co and subsidiaries took place on December 31, 2021:

(in thousands of $) | Consolidated balance sheet of Golar LNG Limited | Deconsolidation of Cool Co and subsidiaries | Proforma consolidated balance sheet of Golar LNG Limited post Cool Co and subsidiaries deconsolidation
ASSETS |  |  |
Current assets | 925,597 |  | 145,956 |  | 1,071,553 |
Non-current assets | 4,022,698 |  | (1,258,340) |  | 2,764,358 |
Total assets | 4,948,295 |  | (1,112,384) |  | 3,835,911 |
LIABILITIES AND EQUITY |  |  |
Current liabilities | (1,307,222) |  | 414,377 |  | (892,845) |
Non-current liabilities | (1,463,156) |  | 303,822 |  | (1,159,334) |
Total liabilities | (2,770,378) |  | 718,199 |  | (2,052,179) |
Equity |  |  |
Stockholders' equity | (1,730,650) |  | 219,686 |  | (1,510,964) |
Non-controlling interests | (447,267) |  | 174,499 |  | (272,768) |
Total equity | (2,177,917) |  | 394,185 |  | (1,783,732) |
Total liabilities and equity | (4,948,295) |  | 1,112,384 |  | (3,835,911) |

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