UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-K


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

For the fiscal year ended December 31, ~~2021~~2022


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

For the transition period from to

Commission File Number: 333-159299

Vantage Drilling International

(Exact name of registrant as specified in its charter)


Cayman Islands		98-1372204
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

c/o Vantage Energy Services, Inc. 777 Post Oak Boulevard, Suite 440, Houston, Texas		77056
(Address of Principal Executive Offices)		(Zip Code)

Registrant’s telephone number, including area code:

(281) 404-4700

Securities registered pursuant to Section 12(b) of the Act: None


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
N/A	N/A	N/A

Securities registered pursuant to 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes  No 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes  No 

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  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  No 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See definitions of “large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

If an emerging growth company, 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. 

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. 

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. 

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to 240.10D-1(b). 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes  No 

The aggregate market value of the Ordinary Shares held by non-affiliates on June 30, ~~2021~~2022, was approximately $1352,~~936~~713,000. The number of the registrant’s Ordinary Shares outstanding as of March 727, ~~2022~~2023 is 13,~~115~~229,~~026~~280 shares.

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TABLE OF CONTENTS

SAFE HARBOR STATEMENT		2
PART I
Item 1.	Business	68
Item 1A.	Risk Factors	1519
Item 1B.	Unresolved Staff Comments	3542
Item 2.	Properties	3542
Item 3.	Legal Proceedings	3542
Item 4.	Mine Safety Disclosures	3542
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	3643
Item 6.	Reserved	3643
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3643
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	4454
Item 8.	Financial Statements and Supplementary Data, including the Report of Independent Registered Public Accounting Firm (BDO USA, LLP; Houston, Texas; PCAOB ID#243)	4655
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	6981
Item 9A.	Controls and Procedures	6981
Item 9B.	Other Information	6982
Item 9C.	Disclosures Regarding Foreign Jurisdictions That Prevent Inspections	6982
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	7083
Item 11.	Executive Compensation	7083
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	7083
Item 13.	Certain Relationships and Related Transactions, and Director Independence	7083
Item 14.	Principal Accounting Fees and Services	7083
PART IV
Item 15.	Exhibits, Financial Statement Schedules	7184
Item 16.	Form 10-K Summary	7286
SIGNATURES		7387

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SAFE HARBOR STATEMENT

This Annual Report on Form 10-K (this “Annual Report”) contains forward-looking statements within the meaning of Section 27A of the Securities Act, and Section 21E of the Exchange Act. These forward-looking statements are included throughout this Annual Report, including under “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.” When used, statements which are not historical in nature, including those containing words such as “anticipate,” “assume,” “believe,” “budget,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “potential,” “predict,” “project,” “should,” “would,” “will,” “future” and similar expressions are intended to identify forward-looking statements in this Annual Report.

These forward-looking statements reflect our current views with respect to future events and are based on assumptions and subject to risks and uncertainties. You should not place undue reliance on these forward-looking statements. Our actual results could differ materially from those anticipated in these forward-looking statements.

Among the factors that could cause actual results to differ materially are the risks and uncertainties described under “Item 1A. Risk Factors,” under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the following:

•

reduced expenditures by oil and gas exploration and production companies;

•

general economic conditions and conditions in the oil and gas industry, including the worldwide supply and demand for oil and gas, and expectations regarding future prices of oil and gas;

•

excess supply of drilling units worldwide;

•

competition within our industry;

•

growing focus on climate change, including regulatory, social and market efforts to address climate change, and its overall impact on the level of investments being directed to fossil ~~fuels~~fuel exploration and production companies and the associated products or services;

•

our current level of indebtedness and ~~our~~the ability to incur additional indebtedness in the near- and long-term;

•

epidemics, pandemics, global health crises, or other public health events and concerns, such as the spread and resulting impact of the COVID-19 pandemic and the effectiveness of associated vaccinations and treatments;

•

governmental, tax and environmental regulations and related actions and legal matters, including the actions taken by governments in response to the spread of COVID-19 and its highly contagious variants and sub-lineages, as well as the results and effects of legal proceedings and governmental audits, assessments, orders and investigations;

•

volatility in the price of commodities due to actions taken by members of OPEC, OPEC+ and other, oil-exploring countries, with respect to oil production levels and announcements of potential changes in such levels, including the ability of members of OPEC+ to agree on and comply with announced supply limitations;

•

the potential for increased production from U.S. shale producers and non-OPEC countries driven by current oil prices, including the effect of such production rates on the overall global oil and gas supply, demand balance and commodity prices;

•

termination or renegotiation of our customer contracts, and the invoking of force majeure clauses, including, but not limited to, as a result of the COVID-19 pandemic;

•

losses on impairment of long-lived assets;

•

any non-compliance with the FCPA and any other anti-corruption laws;

•

the sufficiency of our internal controls, including exposure arising from the failure to (i) establish and maintain effective internal control over financial reporting, in accordance with applicable regulatory requirements, and (ii) fully remediate any material weaknesses identified with respect to such internal controls;

•

operating hazards in the offshore drilling industry;

•

operations in international markets, including geopolitical, global, regional or local economic and financial market risks and challenges, applicability of foreign laws, including foreign labor and employment laws, foreign tax and customs regimes, and foreign currency exchange rate risk;

•

political disturbances, geopolitical instability and tensions, or terrorist attacks, and associated changes in global trade policies and economic sanctions, including, but not limited to, ~~in connection with~~ Russia's invasion of Ukraine in February 2022 and the Russo-Ukrainian War;

ability to obtain indemnity from customers;

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•

adequacy of, or gaps in, insurance coverage upon the occurrence of a catastrophic or other material adverse event;

•

effects of new products and new technology on the market;

•

the occurrence (or recurrence) of cybersecurity incidents, attacks, intrusions or other breaches to our information technology systems;

•

our small number of customers, related concentration and/or the loss of any customers;

•

consolidation of our competitors and suppliers;

•

termination or renegotiation of vendor contracts;

•

changes in the status of pending, or the initiation of new, litigation, claims or proceedings, including our ability to prevail in the defense of any appeal or counterclaim;

•

changes in legislation removing or increasing current applicable limitations of liability;

•

limited mobility of our drilling units between geographic regions;

•

the small size of our fleet and associated vulnerabilities in the case of prolonged downtime of any of our drilling rigs;

•

levels of operating and maintenance costs;

•

our dependence on key personnel;

•

availability of workers and the related labor costs;

•

increased ~~cost~~costs resulting from supply chain constraints, delays and impediments, including, but not limited to, increases in (i) the costs of obtaining supplies, (ii) labor costs, and (iii) freight, transportation and input costs, among others;

•

changes in tax laws, treaties or regulations;

•

credit risks of our key customers and other third parties we engage commercially;

•

compliance with restrictions and covenants in our debt agreements;

•

our recent lack of overall profitability and whether we will generate material revenues or profits in the near- and long-term;

•

~~our~~adverse ~~incorporation~~macroeconomic ~~under~~conditions, ~~the~~including ~~laws~~(i) ofinflationary ~~the~~pressures ~~Cayman~~and ~~Islands~~potential recessionary conditions, as well as actions taken by central banks and regulators across the ~~limited~~world ~~rights~~in an attempt to ~~relief~~reduce, ~~that~~curtail ~~may~~and beaddress ~~available~~such ~~compared~~pressures toand ~~U.S.~~conditions, ~~law;~~and (ii) the failure in March 2023 of Silicon Valley Bank and Signature Bank, and the resulting impact on the stability of the global financial markets at large;

•

our incorporation under the laws of the Cayman Islands and the limited rights to relief that may be available compared to U.S. law;

•

compliance with the Economic Substance Act 2021 (as amended) and the Economic Substance Act 2018 (as amended), among other legislation enacted in the Cayman Islands and Bermuda; and

•

our ability to identify and complete strategic and/or transformational transactions, including acquisitions, dispositions, joint ventures and mergers, as well as the impact that such transactions may have on our operations and financial condition.

Many of these factors are beyond our ability to control or predict. Any, or a combination of these factors, could materially affect our future financial condition or results of operations and the ultimate accuracy of the forward-looking statements. These forward-looking statements are not guarantees of our future performance, and our actual results and future developments may differ materially from those projected in the forward-looking statements. Management cautions against putting undue reliance on forward-looking statements or projecting any future results based on such statements or present or prior earnings levels.

In addition, each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements. We may not update these forward-looking statements, even if our situation changes in the future. All forward-looking statements attributable to us are expressly qualified by these cautionary statements. Additional information concerning factors that could cause actual results to differ materially from those in the forward-looking statements is contained from time to time in filings we may make with the SEC, which may be obtained by contacting us or the SEC. These filings are also available through our website at www.vantagedrilling.com or through the SEC’s Electronic Data Gathering and Analysis Retrieval system (“EDGAR”) at www.sec.gov. The contents of our website are not part of this Annual Report.

Unless the context indicates otherwise, all references to the “Company,” “Vantage Drilling International,” “we,” “our” or “us” refer to Vantage Drilling International and its consolidated subsidiaries. References to “VDI” refer to Vantage Drilling International, a Cayman Islands exempted company and the group parent company.

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~~GLOSSARY~~Unless OFthe ~~TERMS~~context indicates otherwise, all references to the “Company,” “Vantage Drilling International,” “we,” “our” or “us” refer to Vantage Drilling International and its consolidated subsidiaries. References to “VDI” refer to Vantage Drilling International, a Cayman Islands exempted company and the group parent company.

The following terms used in this Annual Report have the following meanings, unless specified elsewhere in this Annual Report:

Abbreviation/Acronym		Definition
10% Second Lien Notes		The Company's 10% Senior Secured Second Lien Notes due 2020
2016 Amended MIP		The Company's Amended and Restated 2016 Management Incentive Plan
2016 Term Loan Facility		The Company's initial term loans in place in connection with the Reorganization Plan
9.25% First Lien Notes		The Company's 9.25% Senior Secured First Lien Notes due November 15, 2023
ADES		ADES International Holding Ltd, an offshore and onshore provider of oil and gas drilling and production services in the Middle East, India and Africa
ADVantage		ADVantage Drilling Services SAE, a joint venture owned 51% by the Company and 49% by ADES
ASC		Accounting Standards Codification
ASU		Accounting Standards Update
Board of Directors		The Company's board of directors
Comparable Year		The year ended December 31, 2020
Conversion		The conversion of all of the Convertible Notes into Ordinary Shares
Convertible Notes		The Company's 1%/12% Step-Up Senior Secured Third Lien Convertible Notes due 2030
COVID-19		Coronavirus disease 2019, a new strain of coronavirus caused by SARS-CoV-2
Current Year		The year ended December 31, 2021
DOJ		U.S. Department of Justice
Drilling Contract		The Agreement for the Provision of Drilling Services for the Titanium Explorer, dated February 4, 2009, between PVIS and VDEEP (and subsequently novated to PAI and VDDI)
EDC		Emerald Driller Company
Effective Date		February 10, 2016, the date the Company emerged from bankruptcy
EPS		Earnings per share
Exchange Act		Securities Exchange Act of 1934, as amended
FASB		Financial Accounting Standards Board
FCPA		U.S. Foreign Corrupt Practices Act, as amended
First Lien Indenture		First Lien Indenture, dated as of November 30, 2018, by and between Vantage Drilling International and U.S. Bank National Association
Investment Company Act		Investment Company Act of 1940, as amended
IRS		U.S. Internal Revenue Service
LSTC		Liabilities Subject to Compromise
MPD		Managed pressure drilling
New Shares		Shares issued by the reorganized Company
Non-U.S. Holder		A beneficial owner of the Ordinary Shares (other than a partnership or other entity or arrangement treated as a partnership for U.S. federal income tax purposes) that is not a U.S. Holder
Offer		An offer by the Company to repurchase up to $75.0 million of the 9.25% First Lien Notes
Offer Expiration Date		11:59 pm (New York City time) on August 2, 2019
OPEC		The Organization of the Petroleum Exporting Countries
OPEC+		The Organization of the Petroleum Exporting Countries plus 10 non-OPEC nations
Ordinary Shares		The Company's ordinary shares, par value $0.001 per share
PAI		Petrobras America, Inc.
PBGs		Performance-based restricted stock units
Petrobras		Petroleo Brasileiro S.A.
Petrobras Agreement		The agreement among VDEEP and VDDI, on the one hand, and the Petrobras Parties, on the other, relating to the Petrobras Award issued in favor of VDEEP and VDDI
Petrobras Award		The award issued by an international arbitration tribunal to VDEEP and VDDI with respect to the Petrobras Parties' breach of the Drilling Contract
Petrobras Parties		Collectively, Petrobras, PAI and PVIS
PIK		Payment-in-kind
PVIS		Petrobras Venezuela Investments & Services, BV
QLE		A qualified liquidity event as defined in the 2016 Amended MIP
Reorganization Plan		The Company's pre-packaged plan of reorganization under Chapter 11 of Title 11 of the U.S. Bankruptcy Code
Restructuring Agreement		The restructuring support agreement among VDC, VDI and a majority of the Company's secured creditors

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ROU		Right-of-use
SEC		Securities and Exchange Commission
Securities Act		Securities Act of 1933, as amended
Tax Election		Tax election filed with the IRS on January 22, 2020, to allow VDI to be treated as a partnership, rather than a corporation, for U.S. federal income tax purposes, with an effective date retroactive to December 9, 2019
TBGs		Time-based restricted stock units
TEV		Total enterprise value
U.S.		United States of America
U.S. GAAP		Accounting principles generally accepted in the United States of America
U.S. Holder		A beneficial owner of the Ordinary Shares that is, for U.S. federal income tax purposes, (i) a citizen or individual resident of the United States, (ii) a corporation (or other entity treated as a corporation for U.S. federal income tax purposes) that was organized under the laws of the United States, any state thereof, or the District of Columbia, (iii) an estate, the income of which is subject to U.S. federal income tax regardless of its source or (iv) a trust, if a U.S. court can exercise primary supervision over the administration of the trust and one or more U.S. persons have the authority to control all substantial decisions of the trust, or such trust has a valid election in effect under applicable treasury regulations to be treated as a U.S. person for U.S. federal income tax purposes
USD or $		U.S. Dollar
VDC		Vantage Drilling Company, the Company's former parent company
VDC Note		A $61.5 million promissory note issued by the Company in favor of VDC
VDDI		Vantage Deepwater Drilling, Inc.
VDI		Vantage Drilling International
VDEEP		Vantage Deepwater Company
VHI		Vantage Holdings International, a subsidiary of VDI
VIE		Variable interest entity

GLOSSARY OF TERMS

The following terms used in this Annual Report have the following meanings, unless specified elsewhere in this Annual Report:

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Abbreviation/Acronym		Definition
2016 Amended MIP		The Company's Amended and Restated 2016 Management Incentive Plan
2016 Term Loan Facility		The Company's initial term loans in place in connection with the Reorganization Plan
9.25% First Lien Notes		The Company's 9.25% Senior Secured First Lien Notes due November 15, 2023
9.50% First Lien Indenture		Indenture, dated as of March 1, 2023, by and between VDI, the guarantors party thereto, and U.S. Bank Trust Company, National Association, as trustee and first lien collateral agent
9.50% First Lien Notes		The Company's 9.50% Senior Secured First Lien Notes due February 15, 2028
ADES		ADES International Holding Ltd, an offshore and onshore provider of oil and gas drilling and production services in the Middle East, India and Africa
ADVantage		ADVantage Drilling Services SAE, a joint venture owned 51% by the Company and 49% by ADES
ASC		Accounting Standards Codification
ASU		Accounting Standards Update
Board of Directors		The Company's board of directors
Conversion		The conversion of all of the Convertible Notes into Ordinary Shares
Convertible Notes		The Company's 1%/12% Step-Up Senior Secured Third Lien Convertible Notes due 2030
COVID-19		Coronavirus disease 2019, a new strain of coronavirus caused by SARS-CoV-2
Current Year		The year ended December 31, 2022
DOJ		U.S. Department of Justice
Drilling Contract		The Agreement for the Provision of Drilling Services for the Titanium Explorer, dated February 4, 2009, between PVIS and VDEEP (and subsequently novated to PAI and VDDI)
EDC		Emerald Driller Company
Effective Date		February 10, 2016, the date the Company emerged from bankruptcy
EPS		Earnings per share
Exchange Act		Securities Exchange Act of 1934, as amended
FASB		Financial Accounting Standards Board
FCPA		U.S. Foreign Corrupt Practices Act, as amended
First Lien Indenture		First Lien Indenture, dated as of November 30, 2018, by and between Vantage Drilling International and U.S. Bank National Association
Investment Company Act		Investment Company Act of 1940, as amended
IRS		U.S. Internal Revenue Service
LSTC		Liabilities Subject to Compromise
MPD		Managed pressure drilling
New Shares		Shares issued by the reorganized Company
Non-U.S. Holder		A beneficial owner of the Ordinary Shares (other than a partnership or other entity or arrangement treated as a partnership for U.S. federal income tax purposes) that is not a U.S. Holder
Offer		An offer by the Company to repurchase up to $75.0 million of the 9.25% First Lien Notes
OPEC		The Organization of the Petroleum Exporting Countries
OPEC+		The Organization of the Petroleum Exporting Countries plus 10 non-OPEC nations
Ordinary Shares		The Company's ordinary shares, par value $0.001 per share
PBGs		Performance-based restricted stock units
Petrobras		Petroleo Brasileiro S.A.
PIK		Payment-in-kind
Previous Year		The year ended December 31, 2020
Prior Year		The year ended December 31, 2021
QLE		A qualified liquidity event as defined in the 2016 Amended MIP
Reorganization Plan		The Company's pre-packaged plan of reorganization under Chapter 11 of Title 11 of the U.S. Bankruptcy Code
Restructuring Agreement		The restructuring support agreement among VDC, VDI and a majority of the Company's secured creditors
ROU		Right-of-use
Russo-Ukrainian War		The ongoing war resulting from Russia's invasion of Ukraine in February 2022
SEC		Securities and Exchange Commission
Securities Act		Securities Act of 1933, as amended
Tax Election		Tax election filed with the IRS on January 22, 2020, to allow VDI to be treated as a partnership, rather than a corporation, for U.S. federal income tax purposes, with an effective date retroactive to December 9, 2019
TBGs		Time-based restricted stock units
TEV		Total enterprise value

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U.S.		United States of America
U.S. GAAP		Accounting principles generally accepted in the United States of America
U.S. Holder		A beneficial owner of the Ordinary Shares that is, for U.S. federal income tax purposes, (i) a citizen or individual resident of the United States, (ii) a corporation (or other entity treated as a corporation for U.S. federal income tax purposes) that was organized under the laws of the United States, any state thereof, or the District of Columbia, (iii) an estate, the income of which is subject to U.S. federal income tax regardless of its source or (iv) a trust, if a U.S. court can exercise primary supervision over the administration of the trust and one or more U.S. persons have the authority to control all substantial decisions of the trust, or such trust has a valid election in effect under applicable treasury regulations to be treated as a U.S. person for U.S. federal income tax purposes
USD or $		U.S. Dollar
VDC		Vantage Drilling Company, the Company's former parent company
VDC Note		A $61.5 million promissory note issued by the Company in favor of VDC
VDI		Vantage Drilling International
VHI		Vantage Holdings International, a subsidiary of VDI
VIE		Variable interest entity

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PART I

Item 1. Business.

Our Company

Vantage Drilling International, a Cayman Islands exempted company, together with its consolidated subsidiaries (collectively the "Company"), is an international offshore drilling company focused on operating a fleet of modern, high specification drilling units. Our principal business is to contract drilling units, related equipment and work crews, primarily on a dayrate basis, to drill oil and gas wells for our customers. Through our fleet of drilling units, we are a provider of offshore contract drilling services to major, national and independent oil and gas companies, focused on international markets. Additionally, for ~~drilling~~third-party ~~units~~ owned bydrilling ~~others~~units, we provide operational and marketing services for operating and stacked rigs, construction supervision services for rigs that are under construction, and preservation management services for rigs that are stacked.

Our Fleet

Our business consists of two operating segments: (1) “Drilling Services,” which includes activities related to owned jackup rigs and drillships; and (2) “Managed Services,” which consists of activities related to rigs owned by third parties that we manage, support or operate through bareboat charters.

Jackups

A jackup rig is a mobile, self-elevating drilling platform equipped with legs that are lowered to the ocean floor until a foundation is established for support, at which point the hull is raised out of the water into position to conduct drilling and workover operations. ~~All~~Both of our premium jackup rigs were built at PPL Shipyard in Singapore. The design of our premium jackup rigs is the Baker Marine Pacific Class 375. These units are ultra-premium jackup rigs with independent legs capable of drilling in up to 375 feet of water, a cantilever drilling floor and a total drilling depth capacity of approximately 30,000 feet.

Drillships

Drillships are self-propelled and suited for drilling in remote locations because of their mobility and large load carrying capacity. While both of our drillships are dynamically positioned and designed for drilling in water depths of up to 12,000 feet, with a total vertical drilling depth capacity of up to 40,000 feet, ~~the~~they ~~Platinum Explorer and Tungsten Explorer~~ are currently equipped to drill in 10,000 feet of water. Each drillship’s hull design has a variable deck load in excess of 20,000 tons and measures approximately 781 feet long by 138 feet wide. Both of our drillships were built at Daewoo Shipbuilding & Marine Engineering shipyard in South Korea.

The following table sets forth certain information concerning our offshore drilling fleet as of March 2513, ~~2022~~2023.

Name	Year Built	Water DepthRating (feet)		Drilling DepthCapacity(feet)		Location	Status
Jackups (2)
Owned Rigs:
Topaz Driller	2009		375		30,000	Tunisia	Operating
Jackups
Soehanah	2007		375		30,000	Thailand	Operating
Topaz Driller	2009		375		30,000	Egypt	Operating
Soehanah	2007		375		30,000	Indonesia	Operating
Drillships (1)
Platinum Explorer	2010		12,000		40,000	India	Operating
Tungsten Explorer	2013		12,000		40,000	~~Egypt~~Namibia	Operating
Third Party Owned Rigs:
Drillships
Polaris	2008		10,000		37,500	India	Operating
Aquarius	2008		10,000		35,000	Spain	Warm stacked
Capella	2008		10,000		37,500	Labuan	Mobilizing
Jackups
Emerald Driller	2008		375		30,000	Qatar	Operating
Sapphire Driller	2009		375		30,000	Qatar	Operating
Aquamarine Driller	2009		375		30,000	Qatar	Operating

(1)

The drillships are designed to drill in up to 12,000 feet of water and are currently equipped to drill in 10,000 feet of water.

On December 20, 2021, we entered into the ADES Purchase Agreement (as defined below under "Recent Developments - Share Purchase Agreement to Sell EDC to ADES Arabia Holding and Entry into the ADES Global Strategic Alliance") to sell EDC which owns the Emerald Driller, Sapphire Driller and Aquamarine Driller. These rigs are currently classified as held for sale on our Consolidated Balance Sheets as of December 31, 2021.8

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Recent Developments

~~Ongoing~~Redemption ~~Impact~~ of the ~~COVID-19~~9.25% ~~Pandemic~~First ~~and~~Lien ~~Geopolitical Instability Caused by the Conflict in Ukraine~~Notes

~~The~~On ~~global~~November ~~spread~~22, ~~of COVID-19~~2022, ~~including~~the ~~its~~Company ~~highly~~issued ~~contagious~~a ~~variants~~notice ~~and~~of ~~sub-lineages,~~partial ~~continues~~redemption to ~~pose~~the ~~significant~~then ~~risks~~existing ~~and~~recordholders ~~challenges~~(the ~~worldwide,~~“Notice ~~and~~of ~~has~~Partial ~~caused~~Redemption”) ~~and~~of ~~continues~~the to9.25% ~~cause~~First ~~widespread~~Lien ~~illness~~Notes. On ~~and~~February ~~significant~~3, ~~loss~~2023, ofthe ~~life,~~Company ~~leading~~subsequently ~~governments~~issued ~~across~~a ~~the~~notice ~~world~~of tofull ~~impose~~conditional ~~and~~redemption ~~re-impose~~to ~~severely~~the ~~stringent~~then ~~and~~existing ~~extensive~~recordholders ~~limitations~~(the on“Notice ~~movement~~of ~~and~~Full ~~human~~Conditional ~~interaction,~~Redemption”) ~~with~~of ~~certain~~the ~~countries,~~9.25% ~~including~~First ~~those~~Lien ~~where~~Notes. The we9.25% ~~maintain~~First ~~significant~~Lien ~~operations~~Notes ~~and~~were ~~derive~~redeemed ~~material~~in ~~revenue,~~full ~~implementing~~on ~~quarantine~~March 6, ~~testing~~2023 ~~and~~with ~~vaccination~~proceeds ~~requirements. These~~derived ~~governmental~~from ~~reactions~~the toissuance of the ~~COVID-19~~9.50% ~~pandemic,~~First asLien ~~well~~Notes (as ~~changes~~discussed tobelow). See ~~and~~“Note ~~extensions~~5. Debt” of ~~such~~the ~~approaches,~~“Notes ~~have led~~ to, ~~and~~Consolidated ~~continue~~Financial toStatements” ~~result~~ in Part II, ~~uncertain~~Item ~~and~~8 ~~volatile~~of ~~economic~~this ~~activity~~Annual ~~worldwide,~~Report ~~including~~for ~~within~~further information regarding the ~~oil~~Notice ~~and~~of ~~gas~~Partial ~~industry~~Redemption. The ~~and~~information ~~the~~discussed ~~regions~~therein ~~and~~is ~~countries~~incorporated by reference in ~~which~~its weentirety ~~operate.~~into this Part I, Item 1 of this Annual Report.

69.50% First Lien Notes Offering

On February 14, 2023, the Company priced an offering of $200.0 million in aggregate principal amount of the 9.50% First Lien Notes and entered into a purchase agreement with several investors pursuant to which the Company agreed to sell the 9.50% First Lien Notes (the “9.50% First Lien Notes Offering”) to the purchasers in reliance on an exemption from registration provided by Section 4(a)(2), Rule 144A and/or Regulation S of the Securities Act. On March 1, 2023, the Company closed the sale of the 9.50% First Lien Notes. See “Note 5. Debt” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report for further information regarding the 9.50% First Lien Notes Offering. The information discussed therein is incorporated by reference in its entirety into this Part I, Item 1 of this Annual Report.

Geopolitical and Market Instability Caused by the Ongoing Russo-Ukrainian War, Inflationary Pressures and Other Macroeconomic Conditions

Over the past 18 months, global oil prices have experienced a robust recovery resulting in the strongest annual performance (on a price-per-barrel basis) since 2012. During 2022, specifically, Brent crude reached a high of approximately $125.00 per barrel in March 2022 although Brent crude ultimately settled at approximately $85.00 per barrel on the last day of trading in December 2022. While our management anticipates that oil and gas prices will remain elevated in the near-term as compared to prices exhibited during the last five years, price volatility is still expected to continue as a result of, among other factors, (i) adverse macroeconomic conditions, including inflationary pressures, potential recessionary conditions, and supply chain impediments and constraints, (ii) changes in oil and gas inventories, (iii) global market demand, (iv) geopolitical instability, armed conflict and social unrest, including the ongoing Russo-Ukrainian War, the associated response undertaken by western nations, such as the implementation, expansion and renewal of broad sanctions, the potential for retaliatory actions on the part of Russia and the overall impact on OPEC+ countries' ability to achieve production targets in the near- and long-term, (v) potential future disagreements among OPEC+ countries regarding the supply of oil, (vi) the potential for increased production and activity from U.S. shale producers and non-OPEC countries driven by the current oil prices, and (vii) the ongoing COVID-19 pandemic, including the transmission and presence of highly contagious and newly discovered variants, and therefore, the Company cannot predict how long oil and gas prices will remain stable or further increase, if at all, or whether they could reverse course and decline.

In particular, the Russo-Ukrainian War has led to, and will likely continue to lead to, geopolitical instability, disruption and volatility in the markets in which we operate. While it is not possible at this time to predict or determine the ultimate consequences of the Russo-Ukrainian War, which could include, among other things, additional sanctions, greater regional instability, embargoes, geopolitical shifts and other material and adverse effects on macroeconomic conditions. Such macroeconomic conditions, including inflationary pressures and potential recessionary conditions (and actions taken or being contemplated by central banks and regulators in an attempt to reduce, curtail and address such pressures and conditions), changes in energy policy, supply chain constraints and limitations, unpredictable financial markets and currency exchange rates, and hydrocarbon price volatility, are likely to continue for the foreseeable future. To the extent the Russo-Ukrainian War and other adverse macroeconomic conditions, including those set forth above, continue (or exacerbate), it could have a lasting impact in the near- and long-term on the (i) operations and financial condition of our business and the businesses of our critical counterparties and (ii) the global economy (see “Risk Factors— The ongoing conflict in Ukraine, including the actual (or perceived threat of an) expansion or exacerbation of such conflict, and the actions undertaken by western nations in response to Russia’s actions, has created, and could continue to create, significant hydrocarbon price volatility and materially impact the global oil and gas markets for the foreseeable future” in Part I, Item 1A. of this Annual Report).

While our management is actively monitoring the foregoing events and its associated financial impact on our business, it is uncertain at this time as to the full magnitude that volatile and uncertain oil and gas prices will have on our financial condition and future results of operations.

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Share Purchase Agreement to Sell EDC to ADES Arabia Holding

On December 6, 2021, VHI, a wholly owned subsidiary of the Company, entered into a certain Share Purchase Agreement (as amended, the “EDC Purchase Agreement”) with ADES Arabia Holding (“ADES Arabia”), which wholly owns ADES, pursuant to which VHI agreed to sell to ADES Arabia all of the issued and outstanding equity of VHI’s wholly owned subsidiary, EDC (the “EDC Sale”). EDC is the owner of the following jackup rigs, each of which are currently operating in Qatar and were included within our Drilling Services segment: the Emerald Driller; the Sapphire Driller; and the Aquamarine Driller. The EDC Purchase Agreement became effective on December 20, 2021 and the transactions contemplated under the EDC Purchase Agreement closed on May 27, 2022 (the “EDC Closing Date”). On the EDC Closing Date, VHI received $170.0 million as purchase price consideration and $30.0 million in certain contract preparation expense reimbursement. In accordance with the terms of the EDC Purchase Agreement, an additional $4.0 million of proceeds was retained in an escrow fund (the “Adjustment Escrow Fund”) as security for potential purchase price adjustments. During the third quarter of 2022, the entirety of the Adjustment Escrow Fund was released to ADES Arabia and a payment of $1.3 million was paid by VHI to ADES Arabia to finalize the purchase price adjustments pursuant to the EDC Purchase Agreement. As a result of these transactions, VHI recognized a net gain of approximately $61.4 million.

Simultaneously with the EDC Sale, certain subsidiaries of the Company and ADES entered into three separate support services agreements (collectively, the "EDC Support Services Agreements"), pursuant to which a subsidiary of the Company agreed to provide, in exchange for customary fees and reimbursements, support services to EDC with respect of the Emerald Driller, Sapphire Driller and Aquamarine Driller for a three-year term.

The Company and ADES also entered into an agreement on December 6, 2021 (the "Collaboration Agreement") to pursue a global strategic alliance to leverage both the EDC Support Services Agreement and ADVantage, the parties’ existing joint venture in Egypt. Pursuant to the Collaboration Agreement, the parties agreed to collaborate on exploring future commercial and operational opportunities.

Tungsten Explorer Contract Award

On June 9, 2022, a subsidiary of VDI entered into a drilling services contract with a subsidiary of TotalEnergies (the “TotalEnergies Contract”) in respect of VDI’s ultra-deepwater drillship, the Tungsten Explorer. The TotalEnergies Contract contains a minimum term of 225 days, which commenced in the first quarter of 2023.

Contractual Arrangements with Advanced Energy Services, S.A.E.

On September 22, 2022, three wholly owned subsidiaries of VHI entered into several related agreements with Advanced Energy Services, S.A.E., a subsidiary of ADES (“ADES SAE” and together with ADES Arabia, the “ADES Group”), including a (i) secondment agreement, (ii) services agreement and (iii) bareboat charter agreement, in each case to support a drilling campaign that will utilize the Topaz Driller jackup rig (collectively, the “ADES Ancillary Agreements”). The ADES Ancillary Agreements generally provide for: (a) reimbursement of loaned employee personnel costs plus a service fee; (b) a fixed fee based on days the rig is drilling; (c) a variable fee based on a percentage of gross margin generated on a monthly basis; and (d) reimbursement for purchases of supplies, equipment and personnel services, and other services provided at the request of ADES SAE. Fees earned in connection with the ADES Ancillary Agreements are included in “Reimbursable and other” in our Consolidated Statement of Operations within the Drilling Services segment as reported in “Note 10. Business Segment and Significant Customer Information” of the “Notes to Consolidated Financial Statements”.

Ongoing Impact of the COVID-19 Pandemic

The global spread of COVID-19, including its highly contagious variants and sub-lineages, continues to pose significant risks and challenges worldwide, and has caused and continues to cause widespread illness and significant loss of life, leading governments across the world to impose and re-impose severely stringent and extensive limitations on movement and human interaction, with certain countries, including those where we maintain significant operations and derive material revenue, implementing quarantine, testing and vaccination requirements. These governmental reactions to the COVID-19 pandemic, as well as changes to and extensions of such approaches, have led to, and continue to result in, uncertain and volatile economic activity worldwide, including within the oil and gas industry and the regions and countries in which we operate. The recent easing of COVID-19 related restrictions in China; (including travel to, from and within China), along with the relatively low immunity rates within the population more generally, could contribute to an increase in the overall rate of infections from (and lead to further variants of) COVID-19. The extent, degree and impact of such increases and the prevalence of new and contagious variants are unknown at this time, but any adverse changes arising from COVID-19 could have a material and adverse effect on our operations and financial condition.

While the Company has previously managed, and continues to actively manage, the business in an attempt to mitigate any ongoing and material impact from the spread of COVID-19, management anticipates that our industry, and the world at large, will need to continue to operate in, and further adapt, to the current environment for the foreseeable future.

The markets generally exhibited a strong recovery in global oil prices during 2021 and our management remains cautiously optimistic with respect to the potential for this trend to continue throughout 2022. However, oil and gas prices are expected to continue to be volatile as a result of, among other factors, (i) the ongoing COVID-19 pandemic, including the transmission and presence of highly contagious and new variants and the pace of vaccine rollouts, (ii) changes in oil and gas inventories, (iii) global market demand, (iv) geopolitical instability, armed conflict and social unrest, including the invasion of Ukraine by Russia in February 2022, the associated response undertaken by western nations, such as the implementation of broad sanctions, and the potential for retaliatory actions on the part of Russia, (v) potential future disagreements among OPEC+ countries regarding the supply of oil, and (vi) the potential for increased production and activity from U.S. shale producers and non-OPEC countries driven by the current oil prices, and therefore, the Company cannot predict how long oil and gas prices will remain stable or further increase, if at all, or whether they could reverse course and decline. In particular, the invasion of Ukraine by Russia has led to, and will likely continue to lead to, geopolitical instability, disruption and volatility in the markets with which we operate. It is not possible at this time to predict or determine the ultimate consequences of the conflict in Ukraine, which could include, among other things, additional sanctions, embargoes, geopolitical shifts and other material and adverse effects on macroeconomic conditions, financial markets, supply chains and currency exchange rates. (see “Risk Factors— The ongoing conflict in Ukraine, including the actual (or perceived threat of an) expansion or exacerbation of such conflict, and the actions undertaken by western nations in response to Russia’s actions, has created, and could continue to create, significant hydrocarbon price volatility and materially impact the global oil and gas markets for the foreseeable future.” in Part I, Item 1A of this Annual Report). Accordingly, while our management is actively monitoring the foregoing events and its associated financial impact our business, it is uncertain at this time as to the full magnitude that volatile and uncertain oil and gas prices will have on our financial condition and future results of operations.10

Share Purchase Agreement to Sell EDC to ADES Arabia Holding and Entry into the ADES Global Strategic Alliance

On December 6, 2021, VHI, a wholly owned subsidiary of the Company, entered into a certain Share Purchase Agreement as amended (the “ADES Purchase Agreement”), with ADES Arabia Holding (“ADES Arabia”), which wholly owns ADES, pursuant to which VHI agreed to sell to ADES Arabia (the "ADES Sale") all of the issued and outstanding equity of VHI’s wholly-owned subsidiary, EDC, for an aggregate purchase price of $170.0 million in cash (the "Cash Consideration"), subject to certain adjustments contemplated by the ADES Purchase Agreement. In addition to the Cash Consideration, the Company will receive from ADES Arabia certain amounts reimbursing it for the Sapphire Driller and Aquamarine Driller Qatari contracts preparation and mobilization costs incurred prior to closing of the ADES Sale. EDC is the owner of the Emerald Driller jackup rig, which is currently operating in Qatar, and the Sapphire Driller jackup rig and the Aquamarine Driller jackup rig, which are expected to commence operations in Qatar in the first and second quarter of 2022, respectively. In addition, certain subsidiaries of the Company and ADES agreed, in connection with the ADES Purchase Agreement, to enter into a three-year support services agreement (the "ADES Support Services Agreement"), pursuant to which a subsidiary of the Company will provide support services to ADES Arabia in respect of the Emerald Driller jackup rig, Sapphire Driller jackup rig and Aquamarine Driller jackup rig. The ADES Purchase Agreement became effective on December 20, 2021. The transactions contemplated by the ADES Purchase Agreement are expected to close during the second quarter of 2022 and are subject to customary closing conditions (see “Risk Factors—The failure to complete the ADES Sale could adversely affect our business and financial condition” in Part I, Item 1A of this Annual Report). The Company continues to evaluate potential uses of the proceeds being derived from the ADES Sale. Under the First Lien Indenture, the Company may only use the proceeds from the ADES Sale to repay, prepay or purchase our senior secured indebtedness (including the 9.25% First Lien Notes), acquire all or substantially all of the assets or capital stock of any other entity engaged in a similar or complementary business to the Company’s lines of business, or make capital expenditures or acquire non-current assets (including vessels and related assets) that are useful in such lines of business (including any deposit or installment payments with respect thereto as well as any expenditures related to the acquisition, construction or “ready for sea” costs of such vessels). To the extent such proceeds are not so applied (or committed to be applied) within one year after receipt, the Company will be required to offer to purchase the 9.25% First Lien Notes with such proceeds.

In addition to the ADES Purchase Agreement, the Company and ADES also entered into an agreement on December 6, 2021 to pursue a global strategic alliance (the “ADES Global Strategic Alliance”) leveraging the ADES Support Services Agreement and ADVantage, the parties’ existing joint venture in Egypt. Pursuant to such agreement, the parties agreed to collaborate on exploring future commercial and operational opportunities.

For further information regarding the ADES Sale and the ADES Global Strategic Alliance, please see the Company’s Current Report on Form 8-K, which was filed with the SEC on December 21, 2021.

Framework, Management and Marketing Agreements with Aquadrill

On February 9, 2021, VHI entered into a Framework Agreement and related Management and Marketing Agreements, as amended on March 16, 2021 (collectively, the “Framework, Management and Marketing Agreements”) with Aquadrill LLC, formerly known as Seadrill Partners LLC (“Aquadrill”), pursuant to which certain subsidiaries of VHI (the “VHI Entities”) agreed to provide operating,

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management and marketing services to Aquadrill and its subsidiaries (the “Aquadrill Entities”) with respect to four deepwater floaters owned by the Aquadrill Entities, which includes two drillships, the Polaris and the Capella, and two semisubmersibles, the Leo and the Sirius. The Framework, Management and Marketing Agreements were subject to the approval of, and were approved by, the U.S. Bankruptcy Court for the Southern District of Texas on March 18, 2021. The Sirius and the Leo have since been sold by Aquadrill and our management of the rigs has therefore concluded. Under the Framework, Management and Marketing Agreements, the Company may earn certain types of fees associated with the management and marketing of the Aquadrill rigs. First, the Company may receive a fixed management fee of $2,000, $4,000, $6,000 or $10,000 per day to manage a cold stacked rig, warm stacked rig, reactivating rig or operating rig, respectively, with some discount on the management fee associated with cold stacked rigs if there are more than one such rigs managed by the Company for Aquadrill. Relatedly, there are certain bonus/malus amounts that are applied to the fixed management fee that are contingent on whether the actual expenditures for a particular rig that is stacked, mobilizing, being reactivated or preparing for a contract exceed or come in under budget. Second, the Company may earn a marketing fee of 1.5% of the effective day rate of a drilling contract secured for the benefit of Aquadrill. Third, the Company may earn a variable fee equal to 13% of the gross margin associated with managing an operating rig for Aquadrill. Finally, all costs incurred by the Company are reimbursed by Aquadrill other than incremental Vantage overhead costs.

In connection with the entry into the Framework, Management and Marketing Agreements, VHI organized a new legal entity, Vantage Financial Management Co., an entity organized in the Cayman Islands (“VFMC”), to provide certain treasury management services to the Aquadrill Entities in respect of the management of the vessels subject to, and covered by, the Framework, Management and Marketing Agreements. VFMC was organized as an unrestricted, indirectly owned subsidiary of the Company and is therefore not subject to the restrictions under the First Lien Indenture.

In October 2021, in connection with the Framework, Management and Marketing Agreements, the Company and Aquadrill agreed to provide the Capella for a two well contract plus two priced optional wells for operations in Indonesia. The drilling campaign is expected to commence in the second quarter of 2022, following the completion of the Capella's current contract, after which the rig will transition to Vantage's management and will undergo scheduled maintenance and subsequently mobilize to Indonesia. The total contract value for the firm portion of the contract is expected to be approximately $42 million and the Company will earn fees pursuant to the Framework, Management and Marketing Agreements with Aquadrill. Furthermore, in January 2022, one of the Company's subsidiaries entered into an agreement with Aquadrill to manage the Aquarius submersible rig, subject to the same terms and conditions outlined in the Framework Management and Marketing Agreements.

Purchase and Sale Agreement to Sell the Titanium Explorer

On December 31, 2020, we entered into a purchase and sale agreement with Best Oasis Limited (the “Buyer”) to sell the Titanium Explorer (the “Titanium Purchase and Sale Agreement”), for an aggregate purchase price of $13.8 million and we classified the rig as held for sale on our Consolidated Balance Sheets. The transaction contemplated by the Titanium Purchase and Sale Agreement closed on March 10, 2021. Pursuant to the Titanium Purchase and Sale Agreement, the Buyer was required to recycle the rig in an environmentally sound manner.

New ONGC Contract for the Platinum Explorer

On February 3, 2021, our ultra-deepwater drillship, the Platinum Explorer, received a letter of award for a two-year contract (the “New ONGC Contract”) from Oil and Natural Gas Company (“ONGC”). The Platinum Explorer concluded its prior three-year contract with ONGC in August 2021 and after being briefly out-of-service for routine maintenance, commenced the New ONGC Contract on November 23, 2021.

Strengths

We believe our primary competitive strengths include the following:

We own and operate a diversified, premium fleet. We have a diversified fleet of four high-specification drilling units that iscan ~~capable~~provide ~~of providing~~ premium drilling services for both shallow water and deepwater applications. We recognize that shallow water and deepwater business cycles may differ, particularly during an industry recovery, and believe our fleet diversity reduces our reliance on any particular market segment. Our fleet currently includes two jackup rigs and two drillships.

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Jackup rigs. We believe that our ultra-premium jackup rigs compare favorably to the majority of the current global jackup rig fleet, which is primarily comprised of rigs that are older, smaller and less capable due to their reliance on, and utilization of, less modern equipment. Each of our jackup rigs ~~is aged 12 years old or less and~~ has a water depth capability of 375 feet and drilling depth capability of 30,000 feet. Our jackup rigs are equipped with offline stand-building systems, which provide significant drilling efficiency and have at least a 1.4 million pound hook load, allowing more demanding wells to be drilled. Each of our jackup rigs have (i) a cantilever reach envelop of 75 x 30 feet, which enables each rig to reach more well slots on a platform without requiring a rig move, (ii) a large deck space, (iii) up to 3,749 tons of variable deck-load, allowing more equipment and supplies to be stored on the rig, and (iv) a 120-person accommodation, all of which we believe bring efficiencies, better logistics and significant cost savings to our customers. As a result, we believe our jackups are generally preferred by clients for their superior and more efficient drilling performance, better and more cost-effective logistics, and consistent activity levels. As demonstrated since 2015, clients have shown a preference for modern jackups, such as ours, with global modern jackup utilization rebounding more rapidly than older rigs.

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preferred by clients for their superior and more efficient drilling performance, better and more cost-effective logistics, and consistent activity levels. As demonstrated since 2015, clients have shown a preference for modern jackups, such as ours, with global modern jackup utilization rebounding more rapidly than older rigs.

Drillships. Both of our ultra-deepwater drillships are designed to drill in up to 12,000 feet of water, and one of our drillships has been further upgraded with a hook load of 2.5 million pounds, which further enhances its ability to drill deep, complex and demanding wells. Our drillships are currently equipped with risers to drill in water depths of up to 10,000 feet, which we believe is the optimal specification for the majority of current ultra-deepwater development projects. However, additional risers could be added to drill in water depths of up to 12,000 feet as needed by our clients. Finally, an MPD system has been installed on the Tungsten Explorer drillship, and we have the ability to equip this MPD on our other drillship. Based on our experience, a significant number of the recent and active requirements for floaters are requesting an MPD system (or a subset of an MPD system called Riser Gas Handling). We believe these active, high-specification and upgraded drillships will position us to secure contracts and command premium dayrates in the long-term.

Our focus on increased efficiency has led to an optimized cost structure. Following the commodity price downturn in 2014, we implemented company-wide cost savings initiatives in an effort to reduce our rig operating expenses and general and administrative expenses through the right- sizing of shore-based teams and centralization of shore-based operational support in Dubai near key areas of operation. Further, we have significantly reduced our rig operating cost through nationalization and regionalization of senior offshore positions and active supply chain management. We believe our optimized cost structure is among the best in the industry and provides us with the flexibility to operate across business cycles and will lead to enhanced profitability in the event of a recovery in the offshore drilling industry.

We are a leading drilling contractor with strong client relationships. We believe that our safety and operational performance, experienced and skilled employees, and modern and highly advanced fleet have produced a track record of high-quality client service and operational safety, efficiency and effectiveness. We have received special recognition from several of our clients for superior drilling services based on key operational metrics, including with respect to safe operations, drilling efficiency, low non-productive time and best contractor performance.

We have a proven management team. Our executive team has a strong reputation for sound execution, customer focus and delivering strong financial performance. Our management team has extensive experience in the oilfield services and offshore drilling industries, as well as experience operating in key global offshore development locations, including the Gulf of Mexico, West Africa, the Middle East, ~~South~~Southeast ~~East~~ Asia and India, with major international and national oil companies as well as independent exploration and production companies. In addition to the members of the management team, we have highly trained personnel operating and maintaining our rigs. We believe that our team’s significant experience, technical expertise and strong client relationships, as well as the functional depth throughout our organization, enhance our ability to deliver superior drilling services to our clients and effectively operate on a global basis.

Strategy

Our principal business objective is to be the preferred provider of premium offshore drilling rig services to the oil and gas industry. Our operating strategy is designed to enable us to provide high-quality, safe and cost-competitive services ~~through the current business cycle~~, positioning us to benefit ~~from an expected increase in demand for offshore drilling and to increase our cash flow and profits. Specifically, we expect to achieve our business objectives through the following strategies:~~

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from an expected increase in demand for offshore drilling in the current business cycle and to increase our cash flow and profits. Specifically, we expect to achieve our business objectives through the following strategies:

Enhanced focus on safety and operational excellence. With cyclical demand for offshore drilling services, excelling in safety and operational ability is a key factor for success. We intend to continue our focus on minimizing safety incidents, while also continually increasing our operational uptime and efficiency. This dual focus is intended to enable us to develop and maintain long-term customer relationships and maximize the utilization of our fleet while also ensuring the safety of our and our customers’ employees and contractors. We intend to maintain our exemplary safety and operational performance through attentive and engaged leadership, safety and operational management systems, ongoing competency and training programs, appropriate incentive structures at all levels and effective management oversight.

Efficiently manage costs to adapt to and withstand a range of market conditions. With a cost-competitive fleet, we believe we are well-positioned to operate across business cycles and achieve enhanced profitability induring the ~~event of a~~ recovery in the offshore drilling industry. We have assembled and deployed an active fleet that we believe is at the low end of the cost-of-supply curve through right sizing and centralization of shore-based support, nationalization and regionalization of senior offshore positions, and active supply chain management. We believe these efforts to manage costs will enable us to maintain our industry-leading fleet utilization while generating positive operational cash flows in a cyclical dayrate environment.

9Maintain high fleet utilization and consistent activity levels to capitalize on customer preferences for active rigs. We enjoy an industry-leading fleet utilization, which serves as a competitive advantage in securing contracts given operators’ strong preference for rigs with consistent activity levels. Consistent activity helps reduce the uncertainty of any associated costs and preparation time for rigs to undertake new contracts. Each of our drilling rigs are currently contracted.

Preserve balance sheet and maintain significant liquidity through business cycles. With approximately $93.3 million cash on our balance sheet as of December 31, 2022 (including $19.2 million of restricted cash) and no near-term debt maturities, we continue to focus on preservation of liquidity given the volatility of the offshore drilling business.

Continue to leverage our efficient operational management platform in order to effectively manage our rigs and the rigs of third parties. Since our emergence from bankruptcy in February of 2016, we have undergone a right sizing of our shore-based and operational management team, and have centralized our operational support base in Dubai, which is central to our areas of operation. In addition, through the use of local and regional offshore personnel, we maintain among the lowest levels of rig operating costs in our industry. These low operating costs, coupled with our active supply chain management, have enabled us to maintain our industry-leading utilization. Furthermore, our efficient platform has positioned us to develop our managed services business, in which we market and operate rigs owned by third parties, including rigs owned by Aquadrill, pursuant to (i) the framework, management, marketing agreements, (as amended from time to time); (ii) other agreements required in various jurisdictions and; (iii) support three jackups owned by EDC, an indirect subsidiary of ADES.

We have entered into a bareboat charter agreement with Aquadrill for the Polaris for its contract with ONGC. While the rig is under the bareboat charter agreement, the management agreement is suspended. The terms of the bareboat charter are consistent with the management agreements, resulting in the same financial impact to us had the rig remained under the management agreement. See “Contract Backlog” below and “Backlog” under “Item 7. Management’s Discussion and Analysis of Financial Conditions and Results of Operations ”.

Maintain high-quality asset portfolio with diverse footprint by selectively pursuing acquisitions that we believe align with our operational model and are likely to increase cash flow. Our balanced fleet of jackup rigs and drillships allows us to address the dynamic opportunity set in the offshore drilling industry. We believe the quality of our jackup rig and drillship fleets, combined with our experience in shallow and deepwater markets, position us to compete in various market segments and geographies. We maintain a young fleet with an average age of approximately thirteen years; accordingly, our high-specification assets enable us to capitalize on the bifurcation in utilization levels between modern and older rigs, and to secure contracts with premium dayrates. Additionally, high-specification modern drilling units generally provide superior and more efficient drilling performance, as well as enhanced and more cost-effective logistics. Newer and more modern drilling units are also generally preferred by crews, which makes it easier to hire and retain high-quality operating personnel. As a result, our fleet is well suited to meet the requirements of customers for efficiently drilling complex wells in demanding locations. To maintain our high-quality asset portfolio, we are focused on disciplined investment in our active drilling fleet to maximize our profitability. Additionally, we have invested in MPD technology for the Tungsten Explorer ultra-deepwater drillship, technology which is currently required by a significant number of the tenders in the market and is becoming

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~~Maintain~~increasingly ~~high~~prevalent ~~fleet~~in ~~utilization~~the ~~and consistent activity levels to capitalize on customer preferences for active rigs. We enjoy an~~ industry~~-leading fleet utilization~~, ~~which~~making ~~serves~~such asdrillship ahighly ~~competitive~~regarded ~~advantage~~and insought ~~securing~~after ~~contracts~~by ~~given operators’ strong preference for rigs with consistent activity levels~~customers. ~~Consistent~~We ~~activity~~have ~~helps reduce~~ the ~~uncertainty~~ability ~~of any associated costs and preparation time for rigs~~ to ~~undertake~~equip ~~new~~this ~~contracts.~~MPD ~~All~~system ofon our ~~jackup~~other ~~rigs are currently contracted. All of our~~ drillships ~~are currently contracted~~.

Preserve balance sheet and maintain significant liquidity through business cycles. With approximately $90.6 million cash on our balance sheet as of December 31, 2021 (including $17.3 million of restricted cash) and no near-term debt maturities, we continue to focus on preservation of liquidity given the volatility of the offshore drilling business.

Continue to leverage our efficient operational management platform in order to effectively manage our rigs and the rigs of third parties. Since our emergence from bankruptcy in February of 2016, we have undergone a right-sizing of our shore-based and operational management team, and have centralized our operational support base in Dubai, which is central to our areas of operation. In addition, through the use of local and regional offshore personnel, we maintain among the lowest levels of rig operating costs in our industry. These low operating costs, coupled with our active supply chain management, have enabled us to maintain our industry-leading utilization. Furthermore, our efficient platform has positioned us to develop our managed services business, in which we market and operate rigs owned by third parties, most recently three floaters owned by Aquadrill, pursuant to the Framework, Management and Marketing Agreements. We plan to further develop this high-margin and asset-light model as we close the ADES Sale and continue to support the Emerald Driller, Sapphire Driller and Aquamarine Driller for the three-year period immediately following the closing of such transaction.

Maintain high-quality asset portfolio with diverse footprint by selectively pursuing acquisitions that we believe align with our operational model and are likely to increase cash flow. Our balanced fleet of jackup rigs and drillships allows us to address the dynamic opportunity set in the offshore drilling industry. We believe the quality of our jackup rig and drillship fleets, combined with our experience in shallow and deepwater markets, position us to compete in various market segments and geographies. We maintain a young fleet with an average age of approximately twelve years; accordingly, our high-specification assets enable us to capitalize on the bifurcation in utilization levels between modern and older rigs, and to secure contracts with premium dayrates. Additionally, high-specification modern drilling units generally provide superior and more efficient drilling performance, as well as enhanced and more cost effective logistics. Newer and more modern drilling units are also generally preferred by crews, which makes it easier to hire and retain high-quality operating personnel. As a result, our fleet is well suited to meet the requirements of customers for efficiently drilling complex wells in demanding locations. To maintain our high-quality asset portfolio, we are focused on disciplined investment in, and the growth of, our active drilling fleet to maximize our profitability. Additionally, we have invested in MPD technology for the Tungsten Explorer ultra-deepwater drillship, technology which is currently required by a significant number of the tenders in the market and is becoming increasingly prevalent in the industry, making such drillship highly regarded and sought after by customers. We have the ability to equip this MPD system on our other drillship.

Our Industry

The offshore contract drilling industry provides drilling, workover and well construction services to oil and gas exploration and production companies through the use of mobile offshore drilling units. Offshore drilling rigs are generally marketed on a worldwide basis as rigs can be moved from one region to another. The cost of moving a rig and the availability of rig-moving vessels may cause the supply and demand balance to vary between regions. However, significant variations between regions do not tend to exist long-term because of rig mobility.

The offshore drilling market generally consists of shallow water (<400 ft.), midwater (>400 ft.), deepwater (>4,000 ft.) and ultra-deepwater (>7,500 ft.). The global shallow water market is serviced primarily by jackups.

Our jackup fleet is focused on the “long-legged” (>350 ft.) high specification market. The drillships that we operate are focused primarily on the ultra-deepwater segment, but can also operate efficiently and cost effectively in the midwater and deepwater markets.

Historically, the offshore drilling industry has been very cyclical with periods of high demand, limited rig supply and high dayrates alternating with periods of low demand, excess rig supply and low dayrates. Periods of low demand and excess rig supply intensify the competition in our industry and often result in some rigs becoming idle for long periods of time. Periods asof ishigh demand and limited (or a shortage of) rig supply could result in the ~~case~~reactivation ~~today.~~of previously stacked rigs and/or the construction of new rigs, which in turn could lead to excess rig supply. As is common throughout the oilfield services industry, offshore drilling is largely driven by actual or anticipated changes in oil and gas prices and capital spending by companies exploring for and producing oil and gas.

In response to the oversupply of drilling rigs which began in 2016, a number of drilling contractors have removed, ~~and continue to remove,~~ older, less competitive rigs from their fleets by either cold stacking the drilling rigs, repurposing rigs for use in other industries or taking them permanently out of service. In addition to ~~the expected increase in~~ scrapping (“recycling”), many offshore drillers, including our competitors, with significant levels of debt on their balance sheets have ~~recently~~previously completed, ~~are currently pursuing,~~ or may elect to pursue in the near-term, debt restructurings (see “Risk Factors—We may not be able to compete effectively against the actions taken by our competitors, which could materially and adversely impact our business operations and financial results” in Part I, Item 1A. of this Annual Report). These debt restructurings may result in lower cost structures, and additional pressure and incentive to recycle rigs. As drillers emerged from these debt restructurings, consolidation in the industry commenced and it is likely that consolidation will continue, reducing the number of industry participants and lowering cost structures. For further information pertaining to our business and trends in our industry, see “Business Outlook” under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations”.

10In response to both market conditions and excessive levels of idle capacity in recent years, there was intense downward pressure on operating dayrates beginning in 2015 as most drilling contractors had preferred to maintain rigs in an active state to mitigate the risks and costs of stacking and reactivating rigs and to benefit from the fact that customers had generally favored operating rigs over reactivated cold-stacked rigs. Prior to the COVID-19 pandemic, this downward pressure on pricing was starting to reverse itself as evidenced by increased demand for our services in 2019 and early 2020, and dayrates were showing signs of general improvement. However, beginning in the second quarter of 2020, with the initial onset, continued spread, and resulting impact of the COVID-19 pandemic, dayrates, rig activity and contract opportunities each came under significant pressure again. However, dayrates began showing signs of improvement during 2021, resembling pricing trends exhibited prior to the onset of COVID-19. This trend continued into 2022, with dayrates in certain regions reaching more than $400,000 in respect of drillships and $125,000 in respect of jackup rigs. Therefore, based on the trends exhibited in 2021 and 2022, our industry appears to be in the strongest position since 2015 with utilization expected to continue to tighten and dayrates expected to either remain at existing elevated levels or increase in the near-term.

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Annual Report). These debt restructurings may result in lower cost structures, and additional pressure and incentive to recycle rigs. As drillers emerged from these debt restructurings, consolidation in the industry commenced and it is likely that consolidation will continue, reducing the number of industry participants and lowering cost structures. The combination of recycling, restructuring and consolidation will be necessary for the industry to regain firmer footing. Any industry recovery will also depend significantly on continued and demonstrable improvement in global macroeconomic conditions, including the ability to mitigate COVID-19's highly contagious variants and mutations (see “Risk Factors—Epidemics, pandemics, global health crises, or other public health events and concerns, including, but not limited to, the continued global spread of COVID-19 could have a material adverse effect on our business, financial position, operating results and cash flows” in Part I, Item 1A of this Annual Report). For further information pertaining to our business and trends in our industry, see “Business Outlook” under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations”.

In response to both market conditions and excessive levels of idle capacity in recent years, there has been intense downward pressure on operating dayrates since 2015 as most drilling contractors had preferred to maintain rigs in an active state to mitigate the risks and costs of stacking and reactivating rigs and to benefit from the fact that customers had generally favored operating rigs over reactivated cold-stacked rigs. Prior to the COVID-19 pandemic, this downward pressure on pricing was starting to reverse itself as evidenced by increased demand for our services in 2019 and early 2020, and dayrates were showing signs of general improvement. However, beginning in the second quarter of 2020, with the initial onset, continued spread, and resulting impact of the COVID-19 pandemic, dayrates, rig activity and contract opportunities each came under significant pressure again. However, dayrates began showing signs of improvement during 2021, resembling pricing trends exhibited prior to the onset of COVID-19.

Customers

Our customers are primarily large multinational oil and gas companies, government owned oil and gas companies and independent oil and gas producers. ~~Contract termination revenue from the Petrobras Parties accounted for approximately 78% of consolidated revenue for the year ended December 31, 2019.~~ For the years ended December 31, ~~2021~~2022, ~~2020~~2021 and ~~2019~~2020, the following customers accounted for more than 10% of our consolidated revenue, in the respective periods:

	~~Year Ended December 31,~~	Year Ended December 31,
	2021	2020		2019 (1)
Customer	Segment	2022			2021			2020
Eni S.p.A (3)	27%	10%		23%
Aquadrill	Managed Services		31	%		7	%		0	%
Oil & Natural Gas Corporation	~~19%~~Drilling Services and Managed Services	~~25%~~	20	23%		19	%		25	%
North Oil Company	13%	---		---
Belayim Petroleum Company (Petrobel)	Drilling Services		10	%		1	%		5	%
Total E&P Qatar	---	17%		13%
Eni S.p.A (1)	Drilling Services		15	%		27	%		10	%
Total E&P Liban SAL	---	14%		---
North Oil Company	Drilling Services		5	%		13	%		0	%
Medco EP	---	12%		---
Total E&P (2)	Drilling Services		1	%		6	%		31	%
Olio Energy Sdn Bhd (2)	---	---		11%
Medco EP	Drilling Services		6	%		0	%		12	%

(1)

~~Amounts~~Includes ~~exclude~~Eni ~~the~~Cyprus ~~contract~~Limited, ~~termination~~Eni ~~revenue~~Montenegro ~~received~~BV ~~from~~and ~~the~~Eni ~~Petrobras~~Congo ~~Parties~~S.A.

(2)

~~Olio~~Includes ~~Energy~~Total ~~Sdn~~E&P ~~Bhd~~Cyprus ~~is a contracting party through which we operate~~B.V., orTotal ~~have~~E&P ~~operated,~~Qatar ~~for Petronas Carigali, a subsidiary of the national oil company of Malaysia,~~ and ~~CPOC,~~Total aE&P ~~joint~~Liban ~~venture between Petronas Carigali JDA limited, a subsidiary of the national oil company of Malaysia, and PTTEP International Limited, a subsidiary of the national oil company of Thailand.~~ SAL

Includes Eni Montenegro BV, Eni Congo S.A. and Eni Gabon S.A.

Drilling Contracts

Our drilling contracts are the result of negotiation with our customers, and most contracts are awarded through competitive bidding against other contractors. Drilling contracts generally provide for payment on a dayrate basis, with higher rates while the drilling unit is operating and lower rates for periods of mobilization or when drilling operations are interrupted or restricted by equipment breakdowns, adverse environmental conditions or other conditions beyond our control. Currently all of our drilling contracts are on a dayrate basis. A dayrate drilling contract generally extends over a period of time covering either the drilling of a single well (or group of wells) or covering a stated term. Certain of our contracts with customers may be cancelable at the option of the customer upon payment of an early termination fee. Such payments may not, however, fully compensate us for the loss of the contract. Contracts also customarily provide for either automatic termination or termination at the option of the customer typically without the payment of any termination fee, under various circumstances such as non-performance, in the event of extensive downtime or impaired performance caused by equipment or operational issues, or sustained periods of downtime due to force majeure events or for convenience by the customer. Many of these events are beyond our control. The contract term in some instances may be extended by the client exercising options for the drilling of additional wells or for an additional term. Our contracts also typically include a provision that allows the client to extend the contract to finish drilling a well-in-progress. During periods of depressed market conditions, our clients may seek to renegotiate drilling contracts to reduce their obligations or may seek to repudiate their contracts. Suspension of drilling contracts will result in the reduction in or loss of dayrate for the period of the suspension. To the extent (i) our customers cancel some of our contracts and we are unable to secure new contracts on a timely basis and on substantially similar terms, (ii) our contracts are suspended for an extended period of time or (iii) a number of our contracts are renegotiated, it could adversely affect our consolidated statements of financial position, results of operations or cash flows.

11The following table sets forth certain information concerning the current contract status of our owned, managed and supported offshore drilling fleet as of March 13, 2023:

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period of time or (iii) a number of our contracts are renegotiated, it could adversely affect our consolidated statements of financial position, results of operations or cash flows.


Name	Region	Contract End Date	Customer
Owned Rigs:
Topaz Driller (1)	North Africa	Q2 2023	ADES Egypt
Soehanah	Southeast Asia	Q3 2023	Medco EP
Platinum Explorer	Southeast Asia	Q4 2023	Oil & Natural Gas Corporation
Tungsten Explorer	Southern Africa	Q1 2024	TotalEnergies
Third Party Owned Rigs:
Polaris (2)	Southeast Asia	Q3 2023	Oil & Natural Gas Corporation
Capella	Southeast Asia	Q2 2024	Eni
Emerald Driller	Qatar	Q2 2024	TotalEnergies
Sapphire Driller	Qatar	Q2 2025	North Oil Company
Aquamarine Driller	Qatar	Q2 2025	North Oil Company

(1)

~~The~~Operated ~~following~~by ~~table~~ADES ~~sets~~Egypt ~~forth~~under ~~certain~~a ~~information~~bareboat ~~concerning the current contract status of our offshore drilling fleet as of March 25, 2022:~~charter.

(2)

Name (1)	Region	Contract End Date	Customer
Topaz Driller	North Africa	Q2 2022	Amilcar Petroleum Operations S.A. Tunisia
Soehanah	Southeast Asia	Q4 2022	Medco EP
Platinum Explorer	India	Q4 2023	Oil & Natural Gas Corporation
Tungsten Explorer	North Africa	Q2 2022	Belayim Petroleum Company

Operated by the Company under a bareboat charter. See “Continue to leverage our efficient operational management platform in order to effectively manage our rigs and the rigs of third parties” under “Strategy” above and “Contract Backlog” (immediately below).

On December 20, 2021, we entered into the ADES Purchase Agreement (as defined above under "Recent Developments - Share Purchase Agreement to Sell EDC to ADES Arabia Holding and Entry into the ADES Global Strategic Alliance") to sell EDC which owns the Emerald Driller, Sapphire Driller and Aquamarine Driller. These rigs are classified as held for sale on our Consolidated Balance Sheets as of December 31, 2021.

Contract Backlog

As of December 31, ~~2021~~2022, our owned fleet had total drilling contract backlog of approximately $~~398~~217.2 million, ~~including~~(includes $~~190~~61.82 million ~~related~~for torigs ~~the~~owned ~~sale~~by ofthird ~~EDC~~parties ~~which~~where ~~owns~~we ~~the~~enter ~~Emerald~~into ~~Driller,~~contracts ~~Sapphire~~directly ~~Driller~~with customers and ~~Aquamarine~~lease ~~Driller,~~the ~~which~~rigs ~~are~~through ~~classified~~bareboat ascharters ~~held~~from ~~for~~the ~~sale~~rig onowners. The ~~our~~terms ~~Consolidated~~of ~~Balance~~the ~~Sheets~~bareboat ~~(see~~charters ~~"Recent~~are ~~Developments~~consistent -with ~~Share~~the ~~Purchase~~management ~~Agreement~~agreements, toresulting ~~Sell~~in ~~EDC~~the tosame ~~ADES~~financial ~~Arabia~~impact ~~Holding~~to ~~and~~us ~~Entry~~had ~~into~~ the ~~ADES~~rigs ~~Global~~remained ~~Strategic~~under ~~Alliance"~~the inmanagement ~~this Part I, Item 1 for additional information)~~agreements. ) We ~~expect~~anticipate that approximately $~~227~~186.92 million of our total contract backlog, ~~including $72.7 million related to the sale of EDC,~~ as of December 31, ~~2021~~2022 will be performed during ~~2022~~2023, with the remainder to be performed in subsequent years.

Competition

The contract drilling industry is highly competitive. Demand for contract drilling and related services is influenced by aseveral ~~number of~~ factors, including the current and expected prices of oil and gas and the expenditures of oil and gas companies for exploration and development of oil and gas. In addition, demand for drilling services remains dependent on a variety of political and economic factors beyond our control, including worldwide demand for oil and gas, the ability of OPEC to set and maintain production levels and pricing, the level of production of non-OPEC countries, including production levels in the U.S. shale plays, and the policies of various governments regarding exploration and development of their oil and gas reserves.

Drilling contracts are generally awarded on a competitive bid or negotiated basis. Pricing (dayrate) is often the primary factor in determining which qualified contractor is awarded a job. Rig availability, capabilities, age and each contractor’s safety performance record and reputation for quality also can be key factors in the determination. Operators also may consider crew experience, rig location and efficiency. We believe that the market for drilling contracts ~~will~~has ~~continue~~tightened toand ~~be highly competitive for the foreseeable future. Certain competitors may have greater financial resources than we do~~therefore, ~~which may better enable them to withstand periods of low~~ utilization, ~~compete~~and ~~more~~day ~~effectively~~rates inare aanticipated ~~low~~to ~~price~~remain ~~environment,~~elevated ~~build~~for ~~new~~the ~~rigs~~foreseeable ~~or acquire existing rigs~~future.

Our competition ranges from large international companies offering a wide range of drilling and other oilfield services to smaller, locally owned companies. Competition for rigs is usually on a global basis, as these rigs are highly mobile and may be moved, although at a cost that is sometimes substantial, from one region to another in response to demand.

Operating Hazards

Our operations are subject to many hazards inherent in the offshore drilling business, including, but not limited to: blowouts, craterings, fires, explosions, equipment failures, loss of well control, loss of hole, damaged or lost equipment and damage or loss from inclement weather or natural disasters.

These hazards could cause personal injury or death, serious damage to or destruction of property and equipment, suspension of drilling operations, or damage to the environment, including damage to producing formations and surrounding areas. Generally, we seek to obtain contractual indemnification from our customers for some of these risks. To the extent not transferred to customers by contract, we seek protection against some of these risks through insurance, including property casualty insurance on our rigs and drilling equipment, protection and indemnity, commercial general liability, which has coverage extension for underground resources and equipment coverage, commercial contract indemnity and commercial umbrella insurance.

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There are risks that are outside of our control. Nonetheless, we believe that we are adequately insured for liability and property damage to others with respect to our operations. However, such insurance may not be sufficient to protect us against liability for all consequences of well disasters, extensive fire damage or damage to the environment. For more information regarding the risks related to our insurance policies, see “Risk Factors—Our business involves numerous operating hazards, and our insurance and contractual indemnity rights may not be adequate to cover our losses” in Part I, Item 1A. of this Annual Report.

Insurance

We maintain insurance coverage that includes coverage for physical damage, third party liability, employer’s liability, war risk, general liability, vessel pollution and other coverage. However, our insurance is subject to exclusions and limitations and there is no assurance that such coverage will adequately protect us against liability from all potential consequences and damages.

Our primary marine package provides for hull and machinery coverage for our drilling units up to a scheduled value for each asset, which we believe approximates replacement cost. The maximum coverage for our ~~seven~~four drilling units, ~~including our three jack-ups, the Emerald Driller, the Aquamarine Driller and the Sapphire Driller, which are classified as held for sale on our Consolidated Balance Sheets,~~ is $~~910~~520.0 million. In addition, we have included Aquadrill owned rigs which are under our management pursuant to the ~~Framework~~framework, ~~Management~~management and ~~Marketing~~marketing ~~Agreements~~agreements in our insurance programs. The policies are subject to certain exclusions, limitations, deductibles and other conditions. Deductibles for physical damage to our jackup rigs and our drillships are $2.5 million and $5.0 million, respectively, per occurrence. Our protection and indemnity policy provides liability coverage limits of $500.0 million per rig. In addition to these policies, we have separate policies providing coverage for onshore general liability, employer’s liability, auto liability and non-owned aircraft liability, with customary coverage, limits and deductibles.

Foreign Regulation

Our operations are conducted in foreign jurisdictions and are subject to, and affected in varying degrees by, governmental laws and regulations in countries in which we operate, including laws, regulations and duties relating to the importation and exportation of and operation of drilling units and other equipment, currency conversions and repatriation, oil and gas exploration and development, environmental protection, taxation of offshore earnings and earnings of expatriate personnel and the use of local employees and suppliers by foreign contractors. Governments in some foreign countries have become increasingly active in regulating and controlling the ownership of concessions and companies holding concessions, the exploration for oil and gas and other aspects of the oil and gas industries in their countries. In some areas of the world, this governmental activity has adversely affected the amount of exploration and development work done by major oil and gas companies and may continue to do so. Furthermore, these regulations have limited the opportunities for international drilling contractors to participate in tenders for contracts or to perform services in certain countries as the governments have strongly favored local service providers. Operations in less developed countries may be subject to legal systems that are not as predictable as those in more developed countries, which can lead to greater uncertainty in legal matters and proceedings.

The shipment of goods, services and technology across international borders subjects us to extensive trade laws and regulations. Our import and export activities are governed by unique customs laws and regulations in each of the countries where we operate. The laws and regulations concerning import and export activity, recordkeeping and reporting, import and export control and economic sanctions are complex and constantly changing. These laws and regulations may be enacted, amended, enforced or interpreted in a manner materially impacting our operations. Governments also may impose economic sanctions against certain countries, persons and other entities that may restrict or prohibit transactions involving such countries, persons and entities. Shipments can be delayed and denied import or export for a variety of reasons, some of which are outside our control and some of which may result from failure to comply with existing legal and regulatory regimes. Shipping delays or denials could cause unscheduled operational downtime.

Governmental and Environmental Regulations

For a discussion of the effects of governmental and environmental regulation on our current operations, see “Risk Factors—Our business is subject to numerous governmental laws and regulations, including those that may impose significant costs and liability on us for environmental and natural resource damages” and “—Public concern and legislative and regulatory initiatives regarding the risks associated with climate change and the environmental and social impacts of fossil fuel extraction and use, and the growing emphasis by investors on investing in companies that are committed to environmental sustainability, could adversely affect our operations, the demand for oil and gas, our reputation and our access to capital and ability to refinance our debt” in Part I, Item 1A. of this Annual Report, all of which is incorporated by reference in its entirety under this section.

Generally. Many aspects of our operations are affected by foreign, federal, state and local governmental laws, rules, regulations and policies that may relate directly or indirectly to the contract drilling industry, including those requiring us to control the discharge of oil and other contaminants into the environment or otherwise relating to environmental protection. Moreover, with the recent change in administration of the U.S. government, it is likely that new legislation, regulatory enforcement actions and executive orders, which are specifically aimed at reducing greenhouse gas emissions, or prohibiting, delaying or restricting oil development activities in certain jurisdictions, will be proposed and adopted in the near-term (see “Risk Factors—Our business is subject to numerous governmental laws

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and regulations, including those that may impose significant costs and liability on us for environmental and natural resource damages” in Part I, Item 1A. of this Annual Report for further information).

We have historically conducted work in the Gulf of Mexico and may conduct such work in the future. Although we are not currently conducting any operations under the jurisdiction of U.S. environmental and natural resource agencies, similar restrictions and concerns apply in the jurisdictions in which we currently operate. These requirements and concerns may be more or less stringent than those associated with the following U.S. laws.

Heightened and Stringent Environmental Regulations and Laws. Heightened environmental concerns have led to greater and more stringent environmental regulations, laws, initiatives and requirements aimed at protecting the environment, including the imposition of strict liability in certain cases, higher drilling costs, and a more difficult and ~~lengthy~~onerous well permitting process in many jurisdictions throughout the world. Furthermore, a variety of initiatives intended to enhance vessel security have also been adopted in certain jurisdictions where we operate. For example, these initiatives may require the development of vessel security plans and on-board installation of automatic information systems to enhance vessel-to-vessel and vessel-to-shore communications. The application of these requirements or the adoption of new or more stringent requirements could have a material adverse effect on our financial condition and results of operations. Although significant capital expenditures may be required to comply with these governmental laws, regulations and initiatives, such compliance has thus far not materially adversely affected our earnings or competitive position as of the date of this Annual Report, and we believe that we are currently in compliance in all material respects with the environmental regulations to which we are subject. While we anticipate that we will continue to make expenditures to comply with governmental and environmental requirements, to date, we have not expended material amounts beyond those amounts spent on our basic rig designs in order to comply and we do not believe that our compliance with such requirements will have a material adverse effect upon our results of operations or competitive position or materially increase our capital expenditures.

Standards Imposed by MARPOL. The International Maritime Organization (the “IMO”), a specialized agency of the United Nations, is responsible for developing measures to improve the safety and security of international shipping and to prevent marine pollution from ships. Among the various international conventions negotiated by the IMO is the International Convention for the Prevention of Pollution from Ships (“MARPOL”). MARPOL imposes environmental standards on the shipping industry relating to oil spills, management of garbage, the handling and disposal of noxious liquids, harmful substances in packaged forms, sewage and air emissions. Annex VI to MARPOL (“Annex IV”) sets limits on sulfur dioxide and nitrogen oxide emissions from ship exhausts and prohibits deliberate emissions of ozone depleting substances. Annex VI also imposes a global cap on the sulfur content of fuel oil and allows for specialized areas to be established internationally with more stringent controls on sulfur emissions. For vessels 400 gross tons and greater, platforms and drilling units, Annex VI imposes various survey and certification requirements. For this purpose, gross tonnage is based on the International Tonnage Certificate for the vessel. The United States has ratified Annex VI. In addition, any drilling units we operate internationally are subject to the requirements of Annex VI in those countries that have implemented its provisions. We believe the drilling units we currently offer for international projects comply with Annex VI, but changes to our equipment and ratifying countries’ regulatory interpretations of the Annex VI requirements could impose additional costs on us, which could be significant.

Requirements Set Forth in the Economic Substance Act 2021 (as amended) of Cayman Islands and the Economic Substance Act 2018 (as amended) of Bermuda. Pursuant to the Economic Substance Act 2021 (as amended) of Cayman Islands and the Economic Substance Act 2018 (as amended) of Bermuda (collectively, the “ES Acts”), a registered entity (other than an entity which is resident for tax purposes in certain jurisdictions outside the Cayman Islands or Bermuda) that carries on as a business any one or more of the “relevant activities” referred to in the ES Acts must comply with economic substance requirements. In particular, the ES Acts could require covered entities to maintain an adequate level of qualified employees in the Cayman Islands and/or Bermuda, incur an adequate level of annual expenditure in the Cayman Islands and/or Bermuda, maintain physical offices and premises in the Cayman Islands and/or Bermuda, or perform core income-generating activities in the Cayman Islands and/or Bermuda. The list of “relevant activities” includes carrying on any one (or more) of the following activities: banking; insurance; fund management; financing; leasing; headquarters; shipping; distribution and service centers; intellectual property; and holding entities. The ES Acts could additionally substantially affect the way we operate our business, which could in turn materially and adversely affect our business, financial condition and results of operations.

Human Capital

Employees and Reporting

As of December 31, ~~2021~~2022, we managed a workforce consisting of approximately ~~1,030~~900 employees worldwide, of which approximately ~~410~~500 were our direct employees. We report on a monthly basis to senior management on headcount, recruitment, compensation, competency and attrition. We also report human capital-related data to the Board of Directors on a quarterly or on an as required basis.

Diversity

The diversity of our workforce is a core part of who we are, and this diversity permeates throughout the organization. As of December 31, 2021, in our shore-based employee population, our personnel represent 26 different nationalities, with approximately 60% coming from Asia, Africa, Latin America and the Middle East. Furthermore, approximately 29% of our shore-based employees are women. With regard to our offshore workforce, our employees represent 32 different nationalities, with more than 51% coming from Asia, Africa, Latin America and the Middle East. Likewise, our management team also has representation from 19 different nationalities.17

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The diversity of our workforce is a core part of who we are, and this diversity permeates throughout the organization. As of December 31, 2022, in our shore-based employee population, our personnel represent 26 different nationalities, with approximately 60% coming from Asia, Africa, Latin America and the Middle East. Furthermore, approximately 27% of our shore-based employees are women. With regard to our offshore workforce, our employees represent 37 different nationalities, with more than 55% coming from Asia, Africa, Latin America and the Middle East. Likewise, our management team also has representation from 19 different nationalities.

Compensation and Benefits

We believe we offer market competitive compensation as well as an attractive benefits package. We are dedicated to hiring and building a strong diverse team offering equal opportunities to realize and develop our team’s full potential.

People Development

We develop and grow our personnel with zero discrimination and strive to add value in the jurisdictions and regions in which we operate. We achieve this by (i) creating local employment, (ii) making commitments to training and development, and (iii) where possible, utilizing local supply chains. Our offshore employees have the opportunity to enhance their competence via our Vantage Competency Assurance Program, which includes state of the art rig simulators located on each rig. This supplements our comprehensive onboarding, induction and on and off-the-job training programs. Our key personnel also complete ethics and bribery training on an annual basis.

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possible, utilizing local supply chains. Our offshore employees have the opportunity to enhance their competence via our Vantage Competency Assurance Program, which includes state of the art rig simulators located on each rig. This supplements our comprehensive onboarding, induction and on and off-the-job training programs. Our key personnel also complete ethics and bribery training on an annual basis.

Quality, Health, Safety and Environment

We are committed to conducting our activities in a manner that (i) protects and prioritizes the health and safety of all of our personnel and (ii) minimizes our environmental footprint in the jurisdictions and regions in which we operate. Our stated vision is to have “A Perfect Day – Every Day,” which includes the paramount objective of having zero incidents in our operations. For the year ended December 31, ~~2021~~2022, we finished the year with a Lost Time Incident Rate of 0.1610 and a Total Recordable Incident Rate of 0.2425. We have focused on, and will continue to emphasize, the following goals and priorities, among others, in order to continue the foregoing trends:

•

Providing visible and active leadership that creates a mature safety culture, which preserves the wellbeing of our personnel and their families;

•

Continuously improving our world-class Quality, Health, Safety and Environment (“QHSE”) management system by continuously measuring and reviewing our overall QHSE performance;

•

Reporting and investigating all incidents and implementing the lessons learned from each such incident;

•

Complying with, and where feasible, exceeding the requirements of applicable laws and regulations;

•

Developing and enhancing our personnel’s technical and systems competence;

•

Systematically identifying hazards and managing the risks and exposures associated with such hazards to a level considered As Low As Reasonably Practicable (ALARP);

•

Caring for and protecting the environment;

•

Maintaining the integrity of our assets through professional operations and sound maintenance practices;

•

Ensuring all personnel are aware of their obligation to promptly ‘Stop’ a job if they notice something unsafe; and

•

Complying with the principles and intent of the Vantage Perfect Day Leadership Foundations.

Available Information

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to section 13(a) or 15(d) of the Exchange Act are available free of charge through our website at www.vantagedrilling.com as soon as practicable after we electronically file such material with the SEC through EDGAR at www.sec.gov. Information contained on or accessible from our website is not incorporated by reference into this Annual Report and should not be considered a part of this Annual Report or any other filing that we make with the SEC.

This Annual Report also contains summaries of the terms of certain agreements that we have entered into that are filed as exhibits to this Annual Report. The descriptions contained in this Annual Report of those agreements do not purport to be complete and are subject to, and qualified in their entirety by reference to, the respective definitive agreements. You may request a copy of the agreements described herein at no cost by writing or telephoning us at the following address: Vantage Drilling International, Attention: General Counsel, c/o Vantage Energy Services, Inc., 777 Post Oak Boulevard, Suite 440, Houston, Texas 77056, phone number (281) 404-4700. ~~You can also obtain copies of any of the agreements that are filed as exhibits to this Annual Report from the SEC through the SEC’s website at www.sec.gov.~~

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You can also obtain copies of any of the agreements that are filed as exhibits to this Annual Report from the SEC through the SEC’s website at www.sec.gov.

Item 1A. Risk Factors.

There are numerous factors that affect our business and operating results, many of which are beyond our control. Immediately below is a summary of the principal factors that might cause our future operating results to differ materially from those currently expected. The risk factors summarized below are not the only risks facing us. Additional discussion of the risks summarized in the “Risk Factor Summary,” as well as other risks that may affect our business and operating results, can be found below under the heading “Risk Factors,” and should be carefully considered and evaluated before making an investment decision regarding our business. Moreover, additional risks and uncertainties not specified herein, not currently known to us or currently deemed to be immaterial also may materially adversely affect our business, financial position, operating results or cash flows.

Risk Factor Summary:

Risks Related to the Operation of our Business:

•

15given the size of our fleet, we are vulnerable to the effects of extended and prolonged downtime of any of our drilling rigs;

•

~~Table~~a small number of ~~Contents~~customers account for a significant portion of our revenues, and the loss of one or more of these customers, including as a result of any merger, acquisition, disposition or consolidation undertaken by any such customer, could materially and adversely affect our financial condition and results of operations;

•

low prices for oil and gas may reduce demand for our services and could have a material adverse effect on our revenue and profitability;

•

our drilling contracts are generally short-term in duration, and we could experience reduced profitability if customers reduce activity levels or if we otherwise fail to secure new drilling contracts or extend existing contracts upon their termination;

•

our level of indebtedness could adversely affect our financial health and prevent us from fulfilling our debt obligations;

•

public concern and legislative and regulatory initiatives regarding the risks associated with climate change and the environmental and social impacts of fossil fuel extraction and use, and the growing emphasis by investors on investing in companies that are committed to environmental sustainability, could adversely affect our operations, the demand for oil and gas, our reputation and our access to capital and ability to refinance our debt;

•

our long-term contracts are subject to the risk of cost increases and variability, which could adversely impact our short- and long-term profitability;

•

we may be required to make substantial capital and operating expenditures to maintain and upgrade our fleet to maintain our competitiveness and to comply with laws and the applicable regulations and standards of governmental authorities and organizations;

•

our business involves numerous operating hazards, and our insurance and contractual indemnity rights may not be adequate to cover our losses associated with such operating hazards;

•

epidemics, pandemics, global health crises, or other public health events and concerns, including, but not limited to, the continued global spread of COVID-19, could have a material adverse effect on our business, financial position, operating results and cash flows;

•

a small number of customers account for a significant portion of our revenues, and the loss of one or more of these customers could materially adversely affect our financial condition and results of operations;

the international nature of our operations creates additional political, economic, legal and other uncertainties not generally associated with domestic operations;

•

we are subject to litigation and other disputes that could have a material and adverse effect on our business operations and financial condition;

•

a low amount of, or reduction in, expenditures by oil and gas exploration and production companies, a decrease in demand for oil and gas, or other related factors, could materially and adversely affect our business;

•

low prices for oil and gas may reduce demand for our services and could have a material adverse effect on our revenue and profitability;

the concentration of revenue with a small number of customers also exposes us to credit risk of these customers for non-payment or contract termination;

•

failure to employ a sufficient number of skilled workers or an increase in labor costs could materially and adversely impact our operations;

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•

there may be limits to our ability to mobilize drilling units between geographic markets and the time and costs of such drilling unit mobilizations may be material to our business;

•

construction projects are subject to risks, including delays and cost overruns, which could have an adverse impact on our liquidity and results of operations;

•

our information technology systems, as well as those of our service and equipment providers and other persons that we engage, are subject to cybersecurity risks and threats;

•

the ongoing conflict in Ukraine, including the actual (or perceived threat of an) expansion or exacerbation of such conflict, and the actions undertaken by western nations in response to Russia’s actions, has created, and could continue to create, significant hydrocarbon price volatility and materially impact the global oil and gas markets for the foreseeable future;

•

we may engage in certain strategic or transformational transactions in the future, including acquisitions, dispositions, mergers and joint ventures, any of which could affect the value or type of our assets and overall financial condition;

Risks Related to Governmental Regulations and Laws:

•

our business is subject to numerous governmental laws and regulations, including those that may impose significant costs and liability on us for environmental and natural resource damages;

•

because VDI is incorporated under the laws of the Cayman Islands, stakeholders may face difficulties in protecting their interests, and their ability to protect their rights through the U.S. federal courts may be limited;

Risks Related to our Financial Condition and Taxes:

•

16material and adverse developments impacting the financial services industry at large, including the occurrence of actual (or widespread concerns regarding the potential occurrence of) defaults, illiquidity, operational failures and non-performance by financial institutions and critical counterparties, could have a material and adverse effect on our business, financial condition and results of operations;

•

~~Table~~we are exposed to potential risks from the requirement that we evaluate our internal controls under Section 404 of ~~Contents~~the Sarbanes-Oxley Act of 2002 (“Section 404”), and if we fail to establish and maintain effective internal control over financial reporting, our operating results, financial condition and ability to operate our business could be materially and adversely affected;

•

changes in tax laws, treaties or regulations, effective tax rates and adverse outcomes resulting from examination of our tax returns could adversely affect our financial results; and

•

distributions made by VDI may reduce a U.S. Holder’s tax basis in the Ordinary Shares, and therefore, U.S. Holders may realize a greater gain on the disposition of their Ordinary Shares than they otherwise may expect, and may have a tax gain even if the price they receive in a disposition of their Ordinary Shares is less than their original tax basis.

Risk Factors:

Risks Related to Operations of our Business

~~Our~~The ~~industry~~size isof ~~highly~~our ~~competitive,~~fleet ~~cyclical~~makes ~~and~~us ~~subject~~vulnerable to ~~intense~~the ~~price~~effects ~~competition~~of prolonged downtime of any of our drilling rigs.

~~Historically,~~Our ~~the~~financial ~~offshore~~condition ~~contract~~is ~~drilling~~substantially ~~industry~~dependent ~~has~~on ~~been~~the ~~cyclical~~continued and ~~volatile~~effective ~~with~~performance ~~periods~~of our existing fleet of ~~high~~drilling ~~demand~~rigs, ~~limited~~all ~~supply~~of ~~and~~which ~~high~~were ~~dayrates~~operational ~~alternating~~during ~~with~~the ~~fluctuating~~year ~~periods~~ended December 31, 2022. Accordingly, given the small size of ~~low~~our ~~demand~~fleet, ~~excess~~the ~~supply~~continued and ~~low~~ongoing ~~dayrates.~~operational ~~Many~~performance ~~offshore~~of ~~drilling~~our ~~units~~rigs ~~are~~is ~~highly~~critical ~~mobile~~to our business and ~~our~~makes ~~competitors~~us ~~may~~vulnerable ~~move~~to ~~drilling~~extended ~~units~~and ~~from~~ongoing ~~region~~downtime. toAny ~~region~~downtime inor ~~response~~suspension toof ~~changes~~operations inof ~~demand. In~~our ~~addition~~fleet, ~~excess~~including ~~supply~~as a result of, ~~delivered~~among ~~and~~other ~~new-build~~factors, ~~rigs~~equipment ~~continue~~breakdowns, torepairs ~~have~~and amaintenance, ~~notable~~supply ~~impact~~chain onconstraints ~~our~~and ~~industry~~related supply shortages, labor strikes and ~~overall~~other ~~market~~work ~~demand. It~~stoppages, isshortages ~~unclear~~of ~~when~~material ~~these~~and ~~new-build~~skilled ~~drilling~~labor, ~~rigs~~surveys ~~will~~by ~~actually~~government beand ~~delivered~~maritime authorities, ifperiodic atclassification ~~all~~surveys, assevere ~~many~~weather ~~rig~~or ~~deliveries~~harsh ~~have~~operating ~~(i)~~conditions, ~~already~~force ~~been~~majeure ~~deferred~~events toand ~~later~~COVID-19-related ~~dates~~delays, orcould ~~(ii)~~have ~~been~~a ~~canceled~~material ~~entirely.~~and ~~Periods~~adverse ofeffect ~~low~~on ~~demand~~our profitability and ~~excess~~ability ~~supply~~to ~~intensify~~generate ~~competition~~revenue. inFurthermore, under certain circumstances, our ~~industry~~contracts ~~and~~may ~~often~~permit ~~result~~customers into ~~some~~terminate contracts early without the payment of ~~our~~any ~~drilling~~termination ~~units~~fees, ~~becoming~~including ~~idle~~as ~~for~~a ~~long~~result of non-performance, periods of ~~time.~~downtime ~~Prolonged~~and impaired performance arising from equipment and/or operational issues, and sustained periods of ~~low~~downtime ~~utilization~~in ~~and~~connection ~~dayrates~~with force majeure events. Additionally, disruptions to or ~~extended~~restrictions ~~idle~~on ~~time~~the ability of our suppliers, ~~could~~manufacturers ~~result~~and service providers to supply parts, equipment or services in the ~~recognition~~jurisdictions ofin ~~impairment~~which ~~charges~~we onoperate, ~~our~~whether ~~drilling~~as ~~units~~a ifresult ~~cash~~of ~~flow~~government ~~estimates~~actions, ~~based~~labor ~~upon~~shortages, ~~information~~the ~~made~~inability ~~available~~ to ~~management~~source atparts ~~the~~or ~~time,~~equipment ~~indicate~~from ~~that~~affected ~~the~~locations, ~~carrying~~or ~~value~~other ofeffects related to the ~~drilling~~COVID-19 ~~units~~pandemic, may ~~not~~have besignificant ~~recoverable.~~ and adverse consequences

~~Our level of indebtedness could adversely affect our financial health and prevent us from fulfilling our debt obligations.~~ 20

As of December 31, 2021, we had approximately $350 million aggregate principal amount of debt outstanding under the 9.25% First Lien Notes. Our level of indebtedness could have significant and adverse effects on our business. For example, our level of indebtedness and the terms of our debt agreements could:

make it more difficult for us to satisfy our financial obligations under our indebtedness and our contractual and commercial commitments and increase the risk that we may default on our debt obligations;

prevent us from raising the funds necessary to repurchase notes tendered to us if we undergo a change of control;

require us to use a substantial portion of our cash flow from operations to pay interest and principal on the notes and other debt, which would reduce the funds available for working capital, capital expenditures and other general corporate purposes;

limit our ability to obtain additional financing for working capital, capital expenditures, acquisitions and other investments, or general corporate purposes, which may limit our ability to execute our business strategy;

limit our ability to refinance our indebtedness on terms that are commercially reasonable, or at all;

heighten our vulnerability to downturns in our business, our industry or in the general economy, and restrict us from exploiting business opportunities or making acquisitions;

place us at a competitive disadvantage compared to those of our competitors that may have proportionately less debt;

limit management’s discretion in operating our business; and

limit our flexibility in planning for, or reacting to, changes in our business, the industry in which we operate or the general economy.

Each of these factors may have a material and adverse effect on our financial condition and viability. Our ability to satisfy our other debt obligations will depend on our future operating performance, which will be affected by prevailing economic conditions and financial, business and other factors affecting our company and industry, many of which are beyond our control.

Public concern and legislative and regulatory initiatives regarding the risks associated with climate change and the environmental and social impacts of fossil fuel extraction and use, and the growing emphasis by investors on investing in companies that are committed to environmental sustainability, could adversely affect our operations, the demand for oil and gas, our reputation and our access to capital and ability to refinance our debt.

Global climate issues, including the emission of greenhouse gases, continue to attract considerable public and scientific attention, and there has been increased focus on the oil and gas industry as a result. Numerous reports, including, the Fifth Assessment Report of the Intergovernmental Panel on Climate Change, have caused concern about the adverse impacts of human activity on the world’s

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~~climate.~~on ~~The~~our ~~adoption~~ability ofto ~~any~~meet ~~legislation~~our orcommitments ~~regulation~~to ~~that~~customers, ~~requires~~including ~~reporting~~by increasing our operating costs and increasing the risk of ~~greenhouse~~rig ~~gases~~downtime, which could in turn result in contract delays or ~~otherwise~~terminations. ~~restricts~~Moreover, ~~emissions~~certain customers may have special termination rights afforded under local law. Therefore, during periods of ~~greenhouse~~challenging ~~gases~~market ~~from~~conditions ~~our~~that ~~operations~~lead to extended downtime, ~~could~~we ~~require~~may usbe subject to ~~incur~~an ~~significant~~increased ~~costs~~risk of our customers seeking to ~~reduce~~repudiate ~~such~~their ~~emissions,~~contracts. Our customers could ~~adversely~~seek ~~affect~~to ~~demand~~renegotiate ~~for~~their ~~the~~contracts ~~oil~~with us by threatening breaches of contract and ~~gas~~applying ~~that~~commercial wepressure, ~~extract~~any of which could result in lower revenue or ~~limit~~the ~~our~~cancellation ~~access~~of tocontracts ~~financial~~with ~~capital~~or without any applicable early termination payments.

~~Over~~We ~~the~~may ~~recent~~experience ~~years,~~downtime ~~sovereign~~as ~~wealth,~~a ~~pension~~result ~~and endowment funds have increased their divestments~~ of ~~fossil~~repairs ~~fuel~~or ~~equities and pressure lenders to limit funding to companies engaged in the extraction of fossil fuels. These efforts have greatly intensified during the COVID-19 pandemic~~maintenance, ~~both~~human ~~in the United States and throughout the world. For example~~error, ~~New~~defective ~~York~~or ~~State’s~~failed ~~Pension Fund~~equipment, ~~which~~or ~~had~~delays ~~already~~waiting divested from nearly two dozen thermal coal companies in July 2020, announced in December 2020 that it would seek to divest from fossil fuel stocks by 2025 and sell its shares in other companies that contribute to climate change by 2040. Likewise, in January 2021, two of New York City’s largest pension funds, the New York City Employees’ Retirement System and the New York City Teachers’ Retirement System, approved the divestment of approximately $4.0 billion from fossil fuel companies, and the New York City Board of Education Retirement System is expected to follow suit. Furthermore, Sweden’s state-backed pension funds were recently admonished by the Swedish Society for ~~Nature~~replacement Conservation, one of Sweden’s largest climate organizations, for continuing to invest in fossil-fuel companies, and recent proposed changes to the ethical investment guidelines for the Government Pension Fund Global, Norway’s sovereign wealth fund, could result in the fund selling approximately €910 million of its holdingsparts. ~~More~~ recently, universities in the United States, including Yale, Princeton, Stanford, the Massachusetts Institute of Technology and Vanderbilt, have faced scrutiny and pressure to divest from the fossil fuel industry, and in February 2022, students from such universities filed complaints with the attorneys general of their respective states requesting an investigation of alleged breaches of the Uniform Prudent Management of Institutional Funds Act.

~~The~~Our ~~initiatives~~operations ~~aimed~~may atbe ~~limiting~~suspended ~~climate~~because ~~change and reducing air pollution and the emission~~ of ~~greenhouse~~machinery ~~gases~~breakdowns, ~~including~~human ~~divestment from the oil and gas industry~~error, ~~could~~abnormal ~~significantly~~operating ~~interfere with our operations~~conditions, ~~business~~failure ~~activities,~~of ~~and~~subcontractors ~~ability~~ to ~~access~~perform ~~the~~or ~~capital~~supply ~~markets~~goods ~~and~~or ~~refinance our debt. Likewise~~services, ~~successful~~delays ~~divestment~~on ~~efforts~~replacement inparts ~~the oil and gas industry could materially and adversely impact prices of our debt~~ or ~~equity~~personnel ~~securities. Given that members of the investment community have continued to heavily factor in~~shortages, ~~and~~which will likely continue in the near-term to assess, a company’s commitment to environmental, social and governance (“ESG”)-related initiatives and sustainability performance as part of its overall investment strategy and thesis, investors, including large institutional investors, investment advisors and large sovereign wealth, pension and endowment funds, could elect to forego their investment in us to the extent we fail to satisfy such metrics. Such investors may also continue to accelerate their commitment to increasing the overall percentage of their portfolios that are allocated towards companies that have shown significant commitment to ESG-related matters and environmental sustainability. In light of the foregoing, investors may seek to re-allocate portions of their capital away from deepwater projects. These concerns and the uncertainty around global oil and gas prices may cause ~~deepwater~~us ~~projects~~ to ~~become~~experience ~~one~~operational ofdowntime ~~the least attractive areas for investment by our clients given the large capital requirements~~ and ~~the significant amount of time between discovery and production of oil and/or gas. Separately, we~~ could ~~lose~~have ~~existing~~an ~~investors~~adverse ineffect ~~their~~on ~~entirety if we or~~ our ~~securities~~results ~~fail to meet the ESG-related standards and initiatives being sought and prioritized by such investors. Our failure to satisfy such metrics could also harm our overall reputation amongst members~~ of ~~the investment community, our critical counterparties and in the markets more generally~~operations.

~~Furthermore,~~A ~~the~~small ~~increased~~number ~~focus~~of bycustomers ~~the~~account ~~investment~~for ~~community~~a onsignificant ~~ESG-related~~portion ~~practices~~of ~~and~~our ~~disclosures~~revenues, ~~including emission rates~~ and ~~overall impacts to global climate, has created, and will create for~~ the ~~foreseeable~~loss ~~future,~~of ~~increased~~one ~~pressure~~or ~~regarding~~more ~~the enhancement~~ of, ~~and~~these ~~modification~~customers ~~to,~~could ~~the~~materially ~~disclosure~~adversely ~~and~~affect ~~governance practices in~~ our ~~industry. For~~financial ~~example,~~condition ~~BlackRock,~~and ~~one~~results of ~~the~~operations. ~~largest~~The ~~asset~~concentration ~~managers~~of inrevenue ~~the~~with ~~world,~~a ~~which~~small ~~previously~~number ~~affirmed~~of ~~its~~customers ~~commitment~~also toexposes ~~divest~~us ~~from investments in fossil fuels due~~ to ~~concerns~~credit ~~over~~risk ~~climate~~of ~~change,~~these ~~recently~~customers ~~called~~ for ~~the oil companies and other polluting~~non-~~generating~~payment ~~industries~~or itcontract ~~invests in to disclose their carbons emissions and set clear targets to decrease the amounts of such pollution~~termination. ~~As a result, we currently face, and could continue to face, increasing pressure regarding our ESG related practices and disclosures.~~

~~Lastly,~~We ~~increased~~derive ~~attention~~a ~~regarding~~significant ~~the~~portion ~~risks~~ of ~~climate~~our ~~change~~revenues ~~and~~from ~~the~~a ~~emission~~few ofcustomers. Four ~~greenhouse~~customers ~~gases~~accounted ~~augments~~for ~~the~~approximately ~~possibility~~76% of ~~litigation~~our orrevenue ~~investigations~~during ~~being~~the ~~brought~~fiscal byyear ~~public~~ended ~~and~~December ~~private~~31, ~~entities~~2022. ~~against~~Our ~~oil~~financial condition and ~~gas~~results ~~companies~~of inoperations ~~connection~~could ~~with~~be ~~their~~materially ~~greenhouse~~and ~~emissions.~~adversely ~~Should~~affected weif beany ~~targeted~~one byof ~~any~~these ~~such~~customers ~~litigation~~interrupts or ~~investigations,~~curtails wetheir ~~may incur liability~~activities, ~~which,~~fails to pay for the ~~extent~~services that ~~political~~have orbeen ~~societal~~performed, ~~pressures~~terminates ortheir ~~other~~contracts, ~~factors~~fails ~~are~~to ~~involved,~~renew ~~could~~their beexisting ~~imposed~~contracts ~~without~~or ~~regard~~refuses to ~~the~~award ~~causation~~new ~~of,~~contracts orand ~~contribution~~we are unable to, ~~the~~enter ~~asserted~~into ~~damage,~~contracts orwith tonew ~~other~~customers ~~mitigating~~on ~~factors~~comparable terms.

Low prices for oil and gas may reduce demand for our services and could have a material adverse effect on our revenue and profitability.

Demand for our services depends on oil and gas industry activity and expenditure levels that are directly affected by trends in oil and gas prices. In addition, demand for our services is particularly sensitive to the level of exploration, development and production activity of and the corresponding capital spending by, oil and gas companies. Any prolonged weakness in oil and gas prices could depress the near-term levels of exploration, development and production activity. Perceptions of longer-term lower oil and gas prices by oil and gas companies could similarly reduce or defer major expenditures given the long-term nature of many large-scale development projects. Lower levels of activity result in a corresponding decline in the demand for our services, which could have a material adverse effect on our revenue and profitability. Additionally, these factors may adversely impact our financial position if they are determined to cause an impairment of our long-lived assets.

Our drilling contracts are generally short-term in duration, and we could experience reduced profitability if customers reduce activity levels or if we otherwise fail to secure new drilling contracts or extend existing contracts upon their termination.

Many of our drilling contracts are short-term, and oil and gas companies tend to reduce shallow water activity levels quickly in response to downward changes in oil and gas prices. Due to the short-term nature of most of our drilling contracts, a decline in market conditions can quickly and significantly affect our business if customers reduce their levels of operations. We may not be able to secure new contracts for our vessels or extend contracts on favorable terms, if at all, or satisfy any conditions precedent to finalizing any letters of intent or award with respect to our vessels. This could result in one or more of our vessels being idle for an extended period of time, which could adversely affect our profitability, financial position, results of operations and cash flows.

18Our industry is highly competitive, cyclical and subject to intense price competition.

Historically, the offshore contract drilling industry has been cyclical and volatile with periods of high demand, limited supply and high dayrates alternating with fluctuating periods of low demand, excess supply and low dayrates. Many offshore drilling units are highly mobile and our competitors may move drilling units from region to region in response to changes in demand. In addition, excess supply of delivered and new-build rigs continue to have a notable impact on our industry and overall market demand. It is unclear when these new-build drilling rigs will actually be delivered, if at all, as many rig deliveries have (i) already been deferred to later dates, or (ii) been canceled entirely. Periods of low demand and excess supply intensify competition in our industry and often result in some of our drilling units becoming idle for long periods of time. Prolonged periods of low utilization and dayrates, or extended idle time, could result in the recognition of impairment charges on our drilling units if cash flow estimates, based upon information made available to management at the time, indicate that the carrying value of the drilling units may not be recoverable.

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Our long-term contracts are subject to the risk of cost increases and variances, any of which could adversely impact our profitability in both the near- and long-term.

The costs to operate our business generally increase as the demand for contract drilling services and skilled labor increases. While some of our contracts include cost escalation provisions that allow changes to our dayrate based on stipulated cost increases or decreases, the timing and amount earned from these dayrate adjustments may cause fluctuations in the costs we actually incur, and many contracts do not allow for such dayrate adjustments. During times of reduced demand, reductions in costs may not be immediately available as portions of the crew may be required to prepare our rigs for stacking, after which time the crew members are assigned to active rigs or dismissed. Moreover, as our rigs are mobilized from one geographic location to another, the labor and other operating and maintenance costs can vary significantly. In periods of increasing activity and when the number of operating units in our areas of operation increases, either because of new construction, re-activation of idle units or the mobilization of units into the region, shortages of qualified personnel could arise, creating upward pressure on wages and difficulty in staffing. Equipment maintenance expenses fluctuate depending upon the type of activity a drilling rig is performing and the age and condition of the equipment. Contract preparation expenses vary based on the scope and length of contract preparation required.

We may be required to make substantial capital and operating expenditures to maintain and upgrade our fleet to maintain our competitiveness and to comply with laws and the applicable regulations and standards of governmental authorities and organizations, each of which could negatively affect our financial condition, results of operations and cash flows.

Our business is highly capital intensive and dependent on having sufficient cash flow and or available sources of financing in order to fund capital expenditure requirements. We can provide no assurance that we will have access to adequate or economical sources of capital to fund necessary capital expenditures. Such capital expenditures could increase as a result of changes in, among other things, any of the following:

•

the cost of labor and materials;

•

customer requirements;

•

fleet size;

•

the cost of replacement parts for existing drilling rigs;

•

the geographic location of the drilling rigs;

•

the length of drilling contracts;

•

governmental regulations and maritime self-regulatory organization and technical standards relating to safety, security or the environment; and

•

industry standards.

Changes in offshore drilling technology, customer requirements for new or upgraded equipment and competition within our industry may require us to make significant capital expenditures in order to maintain our competitiveness. In addition, changes in governmental regulations, safety or other equipment standards, as well as compliance with standards imposed by maritime self-regulatory organizations, may require us to make additional unforeseen capital expenditures. As a result, we may be required to take our rigs out of service for extended periods of time, with corresponding losses of revenues, in order to make such alterations or to add such equipment. In the future, market conditions may not justify these expenditures or enable us to operate our older rigs profitably during the remainder of their economic lives.

In addition, we may require additional capital in the future. If we are unable to fund capital expenditures with our cash flow from operations or sales of non-strategic assets, we may be required to either incur additional borrowings or raise capital through the sale of debt or equity securities. Our ability to access the capital markets may be limited by our financial condition at the time, by certain restrictive covenants under the agreements governing our credit agreement and notes, by changes in laws and regulations or interpretation thereof and by adverse market conditions resulting from, among other things, general economic conditions and contingencies and uncertainties that are beyond our control. For example, the invasion of Ukraine by Russia in February 2022, and the resulting impact of sanctions imposed by western nations against Russia, Russian-backed separatist regions in Ukraine, certain banks, companies, government officials, and other individuals in Russia and Belarus, could adversely impact the global oil and gas markets for the foreseeable future and, in the process, our ability to access additional capital funding sources. If we raise funds by issuing equity securities, existing shareholders may experience dilution. Our failure to obtain the funds for necessary future capital expenditures could have a material adverse effect on our business and on our consolidated statements of financial condition, results of operations and cash flows.

19Our long-term contracts are subject to the risk of cost increases and variances, any of which could adversely impact our profitability in both the near- and long-term.

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Wethe ~~may~~type ~~not~~of beactivity ~~able~~a todrilling ~~compete~~rig ~~effectively~~is ~~against~~performing and the ~~actions~~age ~~taken~~and bycondition ~~our~~of ~~competitors,~~the ~~which~~equipment. ~~could~~Contract ~~materially~~preparation ~~and~~expenses ~~adversely~~vary ~~impact~~based ~~our~~on ~~business~~the ~~operations~~scope and ~~financial~~length ~~results~~of contract preparation required.

Our ~~competitors~~contracts ~~have engaged, and~~ may ~~continue~~be toterminated ~~engage,~~early in ~~the~~certain ~~process~~circumstances ~~of restructuring their respective balance sheets~~ and, inour ~~the~~customers ~~process, reducing their overall cost structure. In addition, it is anticipated that some of these competitors~~ may ~~enter~~seek ~~into~~to ~~strategic~~renegotiate ~~transactions, including mergers, which could provide further cost savings and efficiencies through synergies,~~ the ~~recycling~~terms of ~~assets~~their ~~and~~existing ~~other means. It is possible that such competitors could emerge stronger financially as a result of such transactions and therefore, be better positioned to secure valuable drilling~~ contracts atwith ~~lower rates~~us. ~~The~~ emergence of stronger competitors in an already challenging financial environment could adversely affect our ability to secure critical drilling contracts and thereby adversely affect our business operations and financial condition.

Our drilling contracts may be terminated early in certain circumstances and our customers may seek to renegotiate the terms of their existing drilling contracts with us.

In certain instances, our customers may have the contractual right to terminate, or may seek to renegotiate, their existing drilling contracts with us if we experience excessive downtime, operational issues above the contractual limit or safety-related issues, if the drilling unit is a total loss, if the drilling unit is not delivered to the customer within the period specified in the contract or in other specified circumstances, which include force majeure events beyond the control of either party.

Some of our current ~~drilling~~ contracts, and some ~~drilling~~ contracts that we may enter into in the future, may include terms allowing customers to terminate contracts without cause, with little or no prior notice and without penalty or early termination payments. In addition, we could be required to pay penalties, which could be material, if some of these contracts are terminated due to downtime, operational issues or failure to deliver. Some of the contracts with customers that we enter into in the future may be cancellable at the option of the customer upon payment of a penalty, which may not fully compensate us for the loss of the contract. Early termination of a contract may result in a drilling unit being idle for an extended period of time. The likelihood that a customer may seek to terminate a contract is increased during periods of market weakness. Under most of our contracts, it is an event of default if we file a petition for bankruptcy or reorganization, which would allow the customer to terminate such contract.

Further, during depressed market conditions, a customer may no longer need a unit that is currently under contract or may be able to obtain a comparable unit at a lower dayrate. As a result, customers may seek to renegotiate the terms of their existing drilling contracts or avoid their obligations under those contracts. For a discussion of the termination of, or amendment to, certain of our drilling contracts as a result of the COVID-19 pandemic, see “Risk Factors— Endemics, pandemics, global health crises, or other public health events, threats and concerns, including, but not limited to, the continued global spread of COVID-19, could have a material adverse effect on our business, financial position, operating results and cash flows.”

WePublic ~~may~~concern ~~experience~~and ~~downtime~~legislative asand aregulatory ~~result~~initiatives regarding the risks associated with climate change and the environmental and social impacts of ~~repairs~~fossil orfuel ~~maintenance,~~extraction ~~human~~and ~~error~~use, ~~defective~~and orthe ~~failed~~growing ~~equipment~~emphasis by investors on investing in companies that are committed to environmental sustainability, orcould ~~delays~~adversely ~~waiting~~affect our operations, the demand for ~~replacement~~oil ~~parts.~~and gas, our reputation and our access to capital and ability to refinance our debt.

~~Our~~Global ~~operations~~climate ~~may~~issues, beincluding ~~suspended~~the ~~because~~emission of ~~machinery~~greenhouse ~~breakdowns~~gases, ~~human~~continue ~~error~~to attract considerable public and scientific attention, ~~abnormal~~and ~~operating~~there ~~conditions~~has been increased focus on the oil and gas industry as a result. Numerous reports, ~~failure~~including, ofthe ~~subcontractors~~Fifth toAssessment ~~perform~~Report orof ~~supply~~the ~~goods~~Intergovernmental orPanel ~~services~~on Climate Change, ~~delays~~have caused concern about the adverse impacts of human activity on ~~replacement~~the ~~parts~~world’s climate. The adoption of any legislation or ~~personnel~~regulation ~~shortages~~that requires reporting of greenhouse gases, ~~which~~or ~~may~~otherwise ~~cause~~restricts emissions of greenhouse gases from our operations, could require us to ~~experience~~incur ~~operational~~significant ~~downtime~~costs ~~and~~to reduce such emissions, could ~~have~~adversely anaffect ~~adverse~~demand ~~effect~~for onthe oil and gas that we extract or limit our ~~results~~access ofto ~~operations.~~financial capital.

WeOver ~~may~~the ~~not~~recent beyears, ~~able~~sovereign wealth, pension and endowment funds have increased their divestments of fossil fuel equities and pressure lenders to ~~replace~~limit ~~expiring~~funding orto ~~terminated~~companies ~~contracts~~engaged ~~for~~in ~~our~~the ~~existing~~extraction ~~rigs~~of atfossil ~~dayrates~~fuels. These efforts have greatly intensified during the COVID-19 pandemic, both in the United States and throughout the world. For example, New York State’s Pension Fund, which had already divested from nearly two dozen thermal coal companies in July 2020, announced in December 2020 that ~~are~~it ~~economically~~would ~~feasible~~seek to divest from fossil fuel stocks by 2025 and sell its shares in other companies that contribute to climate change by 2040. Likewise, in January 2021, two of New York City’s largest pension funds, the New York City Employees’ Retirement System and the New York City Teachers’ Retirement System, approved the divestment of approximately $4.0 billion from fossil fuel companies, and the New York City Board of Education Retirement System is expected to follow suit. Furthermore, Sweden’s state-backed pension funds were recently admonished by the Swedish Society for usNature Conservation, one of Sweden’s largest climate organizations, for continuing to invest in fossil-fuel companies, and recent proposed changes to the ethical investment guidelines for the Government Pension Fund Global, Norway’s sovereign wealth fund, could result in the fund selling approximately €910 million of its holdings. More recently, universities in the United States, including Yale, Princeton, Stanford, the Massachusetts Institute of Technology and Vanderbilt, have faced scrutiny and pressure to divest from the fossil fuel industry, and in February 2022, students from such universities filed complaints with the attorneys general of their respective states requesting an investigation of alleged breaches of the Uniform Prudent Management of Institutional Funds Act.

~~Due~~The toinitiatives ~~the~~aimed ~~cyclical~~at ~~nature~~limiting climate change and ~~high~~reducing ~~level~~air ofpollution ~~competition~~and inthe ~~our~~emission ~~industry~~of greenhouse gases, weincluding ~~may~~divestment ~~not~~from bethe ~~able~~oil toand ~~replace~~gas ~~expiring~~industry, orcould ~~terminated~~significantly ~~contracts.~~interfere ~~Our~~with our operations, business activities, and ability to ~~replace~~access ~~expiring~~the orcapital ~~terminated~~markets ~~contracts~~and ~~will~~refinance ~~depend~~our ondebt. ~~prevailing~~Likewise, ~~market~~successful ~~conditions,~~divestment efforts in the ~~specific~~oil ~~needs~~and ofgas ~~our~~industry ~~customers,~~could materially and ~~numerous~~adversely ~~other~~impact ~~factors~~prices ~~beyond~~of our ~~control.~~debt ~~Additionally,~~or ~~any~~equity ~~contracts~~securities. ~~for~~Given ~~our~~that ~~drilling~~members ~~units~~of ~~may~~the beinvestment atcommunity ~~dayrates~~have ~~that~~continued ~~are~~to ~~below~~heavily ~~existing~~factor ~~dayrates~~in, ~~which~~and ~~could~~will ~~have~~likely acontinue ~~material~~in ~~adverse~~the ~~effect~~near-term onto ~~our~~assess, ~~overall~~a ~~business,~~company’s ~~financial~~commitment ~~condition~~to environmental, ~~results~~social and governance (“ESG”)-related initiatives and sustainability performance as part of ~~operations~~its overall investment strategy and ~~future~~thesis, ~~prospects.~~investors, including large institutional

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investors, investment advisors and large sovereign wealth, pension and endowment funds, could elect to forego their investment in us to the extent we fail to satisfy such metrics. Such investors may also continue to accelerate their commitment to increasing the overall percentage of their portfolios that are allocated towards companies that have shown significant commitment to ESG-related matters and environmental sustainability. In light of the foregoing, investors may seek to re-allocate portions of their capital away from deepwater projects. These concerns and the uncertainty around global oil and gas prices may cause deepwater projects to become one of the least attractive areas for investment by our clients given the large capital requirements and the significant amount of time between discovery and production of oil and/or gas. Separately, we could lose existing investors in their entirety if we or our securities fail to meet the ESG-related standards and initiatives being sought and prioritized by such investors. Our failure to satisfy such metrics could also harm our overall reputation amongst members of the investment community, our critical counterparties and in the markets more generally.

Furthermore, the increased focus by the investment community on ESG-related practices and disclosures, including emission rates and overall impacts to global climate, has created, and will create for the foreseeable future, increased pressure regarding the enhancement of, and modification to, the disclosure and governance practices in our industry. For example, BlackRock, one of the largest asset managers in the world, which previously affirmed its commitment to divest from investments in fossil fuels due to concerns over climate change, recently called for the oil companies and other polluting-generating industries it invests in to disclose their carbons emissions and set clear targets to decrease the amounts of such pollution. As a result, we currently face, and could continue to face, increasing pressure regarding our ESG related practices and disclosures.

Lastly, increased attention regarding the risks of climate change and the emission of greenhouse gases augments the possibility of litigation or investigations being brought by public and private entities against oil and gas companies in connection with their greenhouse emissions. Should we be targeted by any such litigation or investigations, we may incur liability, which, to the extent that political or societal pressures or other factors are involved, could be imposed without regard to the causation of, or contribution to, the asserted damage, or to other mitigating factors.

High rates of global inflation and the occurrence of a recession could have a material and adverse impact on our business, results of operations and financial condition.

During 2022, the global markets experienced, and continue to experience, higher rates of inflation as a result of several market factors, including in the form of increased costs pertaining to labor, materials and overhead. As a result of these inflationary pressures, governments in many countries have implemented tighter monetary policies, which could slow the growth rate of local economies and restrict the availability of credit. While we experienced increases in the cost of labor and materials in 2022, we believe that our financial condition and results of operations have thus far not been materially impacted by inflationary pressures. However, to the extent the current rates of inflation and shifts in fiscal and monetary policy result in prolonged and slower growth or a recession, it could have a material and adverse effect on the demand for our products and services and, in the process, our business, results of operations and financial condition as a whole, including with respect to our ability to maintain current levels of gross margin and general and administrative expenses as a percentage of total revenue. Moreover, in the event that a global recession were to occur, it could adversely impact the critical counterparties that we engage, including in the form of a decrease in the products and services they seek to obtain from us.

Our level of indebtedness could adversely affect our financial health and prevent us from fulfilling our debt obligations.

As of March 13, 2023, we had approximately $200 million aggregate principal amount of debt outstanding under the 9.50% First Lien Notes. Our level of indebtedness could have significant and adverse effects on our business. For example, our level of indebtedness and the terms of our debt agreements could:

•

prevent us from raising the funds necessary to repurchase notes tendered to us if we undergo a change of control;

•

require us to use a substantial portion of our cash flow from operations to pay interest and principal on the 9.50% First Lien Notes and other debt, which would reduce the funds available for working capital, capital expenditures and other general corporate purposes;

•

limit our ability to refinance our current or future indebtedness on terms that are commercially reasonable, if at all;

•

heighten our vulnerability to downturns in our business, our industry or in the general economy, and restrict us from exploiting business opportunities or making acquisitions;

•

place us at a competitive disadvantage compared to those of our competitors that may have proportionately less debt;

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•

limit management’s discretion in operating our business; and

•

limit our flexibility in planning for, or reacting to, changes in our business, the industry in which we operate or the general economy.

We may not be able to make principal or interest payments on our existing and future indebtedness, nor refinance such existing and future indebtedness on favorable terms, if at all, and our inability to make such payments on, or refinance, any such indebtedness could materially and adversely affect our liquidity and results of operations.

Our ability to make principal or interest payments on, or to refinance, the 9.50% First Lien Notes or other indebtedness that we incur from time to time depends on our future operational and financial performance, which is subject to financial, business, legislative, regulatory and other factors beyond our control. Our business may not generate sufficient cash flow from operations in the future to service our indebtedness, operations and business. If we are unable to generate sufficient cash flow, we may be required to adopt one or more strategic alternatives, including selling assets, restructuring debt, obtaining additional debt financing, or issuing additional equity securities, any of which may be on terms that are not favorable to us or, in the case of equity securities, highly dilutive to our equityholders. Our ability to refinance the 9.50% First Lien Notes or any other future indebtedness will depend significantly on, and be subject to, prevailing economic and market conditions, including available capital markets, covenants and restrictions in the agreements governing our indebtedness (including the 9.50% First Lien Indenture) and the general condition of the financial markets and the industries in which we operate. We may not be able to engage in any of these activities or on desirable terms, and our inability to refinance such indebtedness (or to do so upon attractive terms) could materially and adversely affect our business, prospects, results of operations, financial condition and cash flows, any of which could in turn result in us defaulting on our existing and future debt obligations and make us vulnerable to adverse industry and general economic conditions. In addition, our existing and future debt agreements may contain restrictive covenants that may prohibit us from adopting any of these alternatives. Our failure to comply with these covenants could result in an event of default which, if not cured or waived, could result in the acceleration of our debt, and would materially and adversely affect our business and financial condition.

Failure to employ a sufficient number of skilled workers could materially and adversely impact our operations.

We require skilled personnel to operate and provide technical services to, and support for, our drilling units. The shortages of qualified personnel or the inability to obtain and retain qualified personnel also could negatively affect the quality and timeliness of our work. In addition, our ability to expand operations depends in part upon our ability to increase the size of the skilled labor force. Due to the extremely weak conditions in the offshore drilling market, the lack of employment and lower wages for offshore personnel have caused and will continue to cause many of our current offshore personnel to permanently leave the industry for employment opportunities in other industries. If industry conditions improve, there is no guarantee these workers will return to the offshore industry resulting in a shortage of qualified personnel that we will be able to employ.

Our business involves numerous operating hazards and is subject to severe weather events, and our insurance and contractual indemnity rights may not be adequate to cover our losses resulting from such hazards and events.

Our operations are subject to the usual hazards inherent in the drilling and operation of oil and gas wells, such as blowouts, reservoir damage, loss of production, loss of well control, punch-throughs, craterings, fires and pollution. The occurrence of any one of these events could result in the suspension of drilling or production operations, claims by the operator and others affected by such events, severe damage to, or destruction of, the property and equipment involved, injury or death to drilling unit personnel, environmental damage and increased insurance costs. We may also be subject to personal injury lawsuits and other claims of drilling unit personnel as a result of our drilling operations. Operations also may be suspended because of machinery breakdowns, abnormal operating conditions, failure of subcontractors to perform or supply goods or services and personnel shortages.

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In addition, our operations are subject to risks inherent in and endemic to marine operations, including capsizing, grounding, collision and loss or damage from severe weather. Severe weather could have a material adverse effect on our operations. Our drilling units could be damaged by high winds, turbulent seas or unstable sea bottom conditions which could potentially cause us to curtail operations for significant periods of time until such damages are repaired.

Damage to the environment could result from our operations, particularly through oil spillage or extensive uncontrolled fires. We may also be subject to property, environmental and other damage claims by host governments, oil and gas companies and other businesses operating offshore and in coastal areas, as well as claims by individuals living in or around coastal areas.

As is customary in our industry, the risks of our operations are partially covered by our insurance and partially by contractual indemnities from our customers. However, insurance policies and contractual rights to indemnify us may not adequately cover losses, and we may not have insurance coverage or rights to indemnify us for all such risks (see “Risks Factors – Customers may be unable or unwilling to indemnify us”). Moreover, pollution and environmental risks generally are not fully insurable. If a significant accident or other event resulting in damage to our drilling units, including severe weather, terrorist acts, war, civil disturbances, pollution or environmental damage, occurs and is not fully covered by insurance or a recoverable indemnity from a customer, it could materially and adversely affect our financial condition and results of operations.

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and we may not have insurance coverage or rights to indemnify us for all such risks (see “Risks Factors – Customers may be unable or unwilling to indemnify us”). Moreover, pollution and environmental risks generally are not fully insurable. If a significant accident or other event resulting in damage to our drilling units, including severe weather, terrorist acts, war, civil disturbances, pollution or environmental damage, occurs and is not fully covered by insurance or a recoverable indemnity from a customer, it could materially and adversely affect our financial condition and results of operations.

Epidemics, pandemics, global health crises, or other public health events, threats and concerns, including, but not limited to, the continued global spread of COVID-19, could have a material adverse effect on our business, financial position, operating results and cash flows.

Epidemics, pandemics, global health crises, or other public health events, threats and concerns, including, but not limited to, the continued global spread of COVID-19, Ebola, the H1N1 flu virus, the Zika virus, Severe Acute Respiratory Syndrome and other highly communicable diseases, outbreaks of which have occurred fairly recently in various parts of the world in which we operate, could adversely impact our operations, the operations of our clients and the global economy, including the worldwide demand for oil and gas and the level of demand for our services. Any quarantine of personnel or the inability to access our offices or rigs could adversely affect our operations. Travel restrictions or operational problems in any part of the world in which we operate, or any reduction in the demand for drilling services caused by public health threats in the future, may adversely affect our business, financial position, operating results and cash flows.

The global spread of COVID-19 in particular, including its highly contagious variants and sub-lineages, continues to pose significant risks and challenges worldwide, and has caused and continues to cause widespread illness and significant loss of life, leading governments across the world to impose and re-impose severely stringent and extensive limitations on movement and human interaction, with certain countries, including those where we maintain significant operations and derive material revenue, implementing quarantine, testing and vaccination requirements. These latest governmental reactions to the COVID-19 pandemic, as well as changes to and extensions of such approaches, have led to, and continue to result in, uncertain and volatile economic activity worldwide, including within the oil and gas industry and the regions and countries in which we operate.

Throughout 2020, we observed deterioration in macroeconomic conditions, oil price and market volatility, and reductions and delays in oil and gas exploration and development plans by operators as a result of the economic impact of the COVID-19 pandemic. We determined these events constituted “triggering events” requiring an assessment for impairment. We recorded a loss on impairment of $128.9 million during the year ended December 31, 2020. During this time, the market experienced a rapid decline in oil prices in response to oil demand concerns due to the economic impacts of COVID-19 and anticipated increases in supply from Russia and OPEC, particularly Saudi Arabia. These actions led to (i) significant weaknesses in oil prices and (ii) ensuing reductions of oil and gas company capital and operating budgets. Moreover, the COVID-19 pandemic has generally affected our customers, suppliers, vendors, and other business partners. If our customers or suppliers experience material and adverse business consequences due to the spread of COVID-19, demand for our services could also be adversely affected, and existing counterparties could seek to invoke “force majeure” clauses under their contracts with us and/or terminate such contracts.

The adverse impact of, and challenges associated with, the COVID-19 pandemic continued throughout 2021, resulting in (i) lower revenue due to terminations of (or amendments to) certain of our drilling contracts and (ii) increased expenses due to higher labor and related costs. We cannot at this time determine with certainty how long these challenges will persist as well as the long-term impact that such challenges may have on our operations on a go-forward basis; however, the Company has been actively managing and continues to actively manage the business in an attempt to mitigate the impact of the foregoing events. In the case of additional expenses incurred as a result of the foregoing matters, the Company undertook significant cost-saving measures, including reductions in salaries and workforce, both onshore and offshore, to reflect the lower operating activity. The extent to which COVID-19 will continue to impact the counterparties in which we engage in business will depend on future developments, which are highly uncertain and cannot be predicted at this time.

We are continuously monitoring our own operations and have taken, and intend to continue to take, appropriate actions to mitigate the risks arising from the COVID-19 pandemic to the best of our abilities. Nevertheless, there can be no assurances that we will be successful in doing so. The ultimate magnitude and effect of the continued spread of COVID-19 globally, and the resulting social, economic and labor instability attributable to COVID-19, cannot be predicted or estimated at this time.

21Like the global economy at large, both our offshore and onshore employees have been significantly impacted by the spread of COVID-19. The impact of such governmental actions have been particularly felt by our personnel working offshore on our rigs. In some cases, our offshore personnel have had to remain onboard the rig on which they serve beyond the usual length of time due to general restrictions on transporting persons onto (and off of) the rig and other offshore personnel have not been able to travel to the applicable offshore locations at all. Even if our offshore personnel are able to successfully travel to the countries where we operate, they may nevertheless be required to self-quarantine for a minimum number of days before continuing on toward the rig. As the health of our workforce is paramount, we have implemented, and will continue to implement for the foreseeable future, precautionary measures to help minimize the risk of our employees being potentially exposed to, or contracting, COVID-19. Our management team has been,

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~~successful~~and inremains, ~~doing~~focused ~~so.~~on ~~The~~mitigating ~~ultimate~~the ~~magnitude~~adverse ~~and~~effects ~~effect~~ of the ~~continued~~ spread of COVID-19, ~~globally~~which has required, and will continue to require, a significant investment of time and resources across the ~~resulting~~entire ~~social~~Company, ~~economic~~thereby diverting time, energy and ~~labor~~resources ~~instability~~from ~~attributable~~other priorities. If these conditions exacerbate our ability to ~~COVID-19~~manage our business may be negatively impacted, ~~cannot~~and preexisting operational and other business risks that we (and our industry) face may be ~~predicted~~heightened, orincluding, ~~estimated~~but atnot ~~this~~limited ~~time~~to, cybersecurity risks and threats. For a discussion regarding cybersecurity risks to our business, see “Risk Factors - Our information technology systems, as well as those of our service and equipment providers and other persons that we engage, are subject to cybersecurity risks and threats.”

Like the global economy at large, both our offshore and onshore employees have been significantly impacted by the spread of COVID-19. The impact of such governmental actions have been particularly felt by our personnel working offshore on our rigs. In some cases, our offshore personnel have had to remain onboard the rig on which they serve beyond the usual length of time due to general restrictions on transporting persons onto (and off of) the rig and other offshore personnel have not been able to travel to the applicable offshore locations at all. Even if our offshore personnel are able to successfully travel to the countries where we operate, they may nevertheless be required to self-quarantine for a minimum number of days before continuing on toward the rig. As the health of our workforce is paramount, we have implemented, and will continue to implement for the foreseeable future, precautionary measures to help minimize the risk of our employees being potentially exposed to, or contracting, COVID-19. Our management team has been, and remains, focused on mitigating the adverse effects of the spread of COVID-19, which has required, and will continue to require, a significant investment of time and resources across the entire Company, thereby diverting time, energy and resources from other priorities. If these conditions exacerbate our ability to manage our business may be negatively impacted, and preexisting operational and other business risks that we (and our industry) face may be heightened, including, but not limited to, cybersecurity risks. For a discussion regarding cybersecurity risks to our business, see “Risk Factors - Our information technology systems and those of our service providers are subject to cybersecurity risks and threats.”

While the COVID-19 pandemic continues to spread worldwide, and the extent of the impact of the COVID-19 pandemic on our operational and financial performance will depend in large part on future developments, which cannot be predicted with confidence at this time. Such developments include, but are not limited to, the duration and further spread of COVID-19, including the discovery of any new strains of COVID-19, the development, availability and effectiveness of treatments or vaccines for COVID-19, and the general resuming of widespread economic activity. Therefore, we can give no assurances that the spread of COVID-19 will not have a material adverse effect on our financial position or results of operations in 2022 and beyond.

A small number of customers account for a significant portion of our revenues, and the loss of one or more of these customers could materially adversely affect our financial condition and results of operations. The concentration of revenue with a small number of customers also exposes us to credit risk of these customers for non-payment or contract termination.

We derive a significant portion of our revenues from a few customers. Three customers accounted for approximately 59% of our revenue during the fiscal year ended December 31, 2021. Our financial condition and results of operations could be materially and adversely affected if any one of these customers interrupts or curtails their activities, fails to pay for the services that have been performed, terminates their contracts, fails to renew their existing contracts or refuses to award new contracts and we are unable to enter into contracts with new customers on comparable terms. The loss of any of our significant customers could materially adversely affect our financial condition and results of operations.

The international nature of our operations creates additional political, economic, legal and other uncertainties not generally associated with domestic operations.

Our business strategy is to operate in international oil and gas producing areas. Our international operations are subject to a number of risks inherent in any business operating in foreign jurisdictions, including:

•

political disturbances, geopolitical instability and tensions, or terrorist attacks, and associated changes in global trade policies and economic sanctions, including, but not limited to, in connection with Russia’s invasion of Ukraine in February 2022;

•

government corruption;

•

potential seizure, expropriation or nationalization of assets;

•

damage to our equipment or violence directed at our employees, including kidnappings;

•

piracy;

•

increased operating costs;

•

complications associated with repairing and replacing equipment in remote locations;

•

repudiation, modification or renegotiation of contracts;

•

limitations on insurance coverage, such as war risk coverage in certain areas;

•

import-export quotas;

•

confiscatory taxation;

•

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work stoppages;

•

unexpected changes in regulatory requirements;

•

wage and price controls;

•

imposition of trade barriers;

•

imposition or changes in enforcement of local content laws;

•

restrictions on currency or capital repatriations;

•

currency fluctuations and devaluations; and

•

other forms of government regulation and economic conditions that are beyond our control.

Our financial condition and results of operations could be susceptible to adverse events beyond our control that may occur in the particular jurisdictions in which we operate our business. Additionally, we may experience currency exchange losses where, at some future date, revenues are received and expenses are paid in nonconvertible currencies or where we do not hedge exposure to a foreign currency. We may also incur losses as a result of an inability to collect revenues because of a shortage of convertible currency available in the country of operation, controls over currency exchange or controls over the repatriation of income or capital.

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Many governments favor or effectively require that drilling contracts be awarded to local contractors or require foreign contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. These practices may result in inefficiencies or put us at a disadvantage when bidding for contracts against local competitors.

Our offshore contract drilling operations are subject to various laws and regulations in countries in which we operate, including laws and regulations relating to the equipment and operation of drilling units, currency conversions and repatriation, oil and gas exploration and development, taxation of offshore earnings and earnings of expatriate personnel, the use of local employees and suppliers by foreign contractors and duties on the importation and exportation of drilling units and other equipment. Governments in some foreign countries have become increasingly active in regulating and controlling the ownership of concessions and companies holding concessions, the exploration for oil and gas and other aspects of the oil and gas industries in their countries. In some areas of the world, this governmental activity has adversely affected the amount of exploration and development work done by major oil and gas companies and may continue to do so. Operations in less developed countries can be subject to legal systems which are not as predictable as those in more developed countries, which can lead to greater uncertainty in legal matters and proceedings.

We may not be able to compete effectively against the actions taken by our competitors, which could materially and adversely impact our business operations and financial results.

Our competitors have engaged, and may continue to engage, in the process of restructuring their respective balance sheets and, in the process, reducing their overall cost structure. In addition, it is anticipated that some of these competitors may enter into strategic transactions, including mergers, which could provide further cost savings and efficiencies through synergies, the recycling of assets and other means. It is possible that such competitors could emerge stronger financially as a result of such transactions and therefore, be better positioned to secure valuable drilling contracts at lower rates. The emergence of stronger competitors in an already challenging financial environment could adversely affect our ability to secure critical drilling contracts and thereby adversely affect our business operations and financial condition.

We may not realize expected revenue from certain framework, management and marketing agreements with Aquadrill.

On February 9, 2021, we entered into a framework agreement and related management and marketing agreements, as amended on March 16, 2021 (collectively, the “Framework, Management and Marketing Agreements”), with Aquadrill LLC (“Aquadrill”), pursuant to which certain subsidiaries of the Company agreed to provide operating, management and marketing services to Aquadrill and its subsidiaries with respect to certain cold stacked, warm stacked, reactivating or operating rigs. We have also entered into a bareboat charter agreement with Aquadrill for the Polaris for its contract with ONGC. Our fee structure is dependent on the type and number of rigs for which we provide our management and marketing services, with some fee discounts for the management and marketing of cold rigs, plus certain (i) bonus and malus amounts above our fixed management fee and (ii) other marketing and variable fees.

In December 2022, Aquadrill entered into a definitive merger agreement with Seadrill Limited (“Seadrill”) pursuant to which Seadrill agreed to acquire Aquadrill (the “Seadrill Transaction”). If the Seadrill Transaction closes, the combined company may discuss modifying the terms of our framework, marketing and management agreements or may terminate those agreements entirely, which Aquadrill is permitted to do upon 90 days’ notice and with the approval of the client under any drilling contract then-in effect. If these agreements are modified or terminated, we may not realize a portion (or the entirety) of the anticipated revenues to be derived under these agreements, which could in turn have a material and adverse effect on our business, financial position, operating results and cash flows.

Our insurance coverage may not be adequate if a catastrophic event occurs.

As a result of the number and significance of catastrophic events in the history of the offshore drilling industry, insurance underwriters have increased insurance premiums and increased restrictions on coverage and have made other coverages unavailable to us on commercially reasonable terms. During the recent industry downturn, in addition to paying lower dayrates, many oil and gas companies have negotiated less favorable terms with respect to risk allocation and indemnity rights in the drilling service contracts to which we are or may become a party.

While we believe we have reasonable policy limits of property, casualty and liability insurance, including coverage for acts of terrorism, with financially sound insurers, we cannot guarantee that our policy limits for property, casualty, liability and business interruption insurance, including coverage for severe weather, terrorist acts, war, civil disturbances, pollution or environmental damage, would be adequate should a catastrophic event occur related to our property, plant or equipment, or that our insurers would have adequate financial resources to sufficiently or fully pay related claims or damages. When any of our coverage expires, or when we seek coverage in the future, we cannot guarantee that adequate coverage will be available, offered at reasonable prices, or offered by insurers with sufficient financial soundness. Additionally, we do not have third party windstorm insurance and we may not have windstorm insurance for any vessel that we operate in the Gulf of Mexico in the future. The occurrence of an incident or incidents affecting any one or more of our drilling units could have a material adverse effect on our financial position and future results of operations if asset damage and/or our liability were to exceed insurance coverage limits or if an insurer was unable to sufficiently or fully pay related claims or damages.

~~We are subject to litigation and other disputes that could have a material and adverse effect on our business operations and financial condition.~~28

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~~COVID-19~~of ~~pandemic~~our ~~may~~drilling ~~result~~units incould ~~investigations,~~have ~~litigation~~a ormaterial ~~legal~~adverse ~~claims against us. We cannot predict with certainty the outcome or~~ effect ofon ~~any~~our ~~dispute,~~financial ~~claim~~position ~~or other litigation matter,~~ and ~~there~~future ~~can~~results ~~be no assurance as to the ultimate outcome~~ of ~~any~~operations ~~litigation~~if orasset ~~dispute. While~~damage ~~we maintain insurance coverage for potential litigation matters~~ and/or ~~disputes,~~our ~~some~~liability ofwere ~~these matters and disputes may not be covered by existing insurance. Moreover,~~ to ~~the~~exceed ~~extent we do maintain such~~ insurance coverage itlimits ~~may not be sufficient, insurers may not remain solvent, other claims may exhaust some~~ or ~~all~~if ofan ~~the~~insurer ~~insurance~~was ~~available~~unable to ussufficiently or ~~insurers~~fully ~~may~~pay ~~interpret~~related ~~our insurance policies such that they refuse to cover all (or a portion) of the losses for which we make~~ claims or may otherwise dispute claims made. The risks associated with these litigation matters and disputes may be difficult to assess or quantify and the existence and magnitude of potential claims often remain unknown for substantial periods of time. Furthermore, litigation and other disputes may have a material adverse effect on us because of potential adverse outcomes, defense costs, the diversion of our management’s resources and other risk factors inherent in litigation or relating to the claims that may arise. Our involvement in any litigation matter or other disputes could cause us to incur significant legal and other associated costs, including the payment of damages.

We are subject to litigation and other disputes that could have a material and adverse effect on our business operations and financial condition.

We are, from time to time, involved in litigation and disputes that could negatively affect our business operations and financial condition. These matters may include, among other things, contract disputes, personal injury claims, environmental claims or proceedings, asbestos and other toxic tort claims, employment and tax matters, claims of infringement of patent and other intellectual property rights, and other litigation that arises in the ordinary course of our business. In addition, during periods of volatile and depressed market conditions, we may be subject to an increased risk of our customers, vendors, current and former employees and others initiating legal proceedings against us. Furthermore, actions or decisions we have taken or may take, or failed to take, as a consequence of the COVID-19 pandemic may result in investigations, litigation or legal claims against us. We cannot predict with certainty the outcome or effect of any dispute, claim or other litigation matter, and there can be no assurance as to the ultimate outcome of any litigation or dispute. While we maintain insurance coverage for potential litigation matters and disputes, some of these matters and disputes may not be covered by existing insurance. Moreover, to the extent we do maintain such insurance coverage it may not be sufficient, insurers may not remain solvent, other claims may exhaust some or all of the insurance available to us or insurers may interpret our insurance policies such that they refuse to cover all (or a portion) of the losses for which we make claims or may otherwise dispute claims made. The risks associated with these litigation matters and disputes may be difficult to assess or quantify and the existence and magnitude of potential claims often remain unknown for substantial periods of time. Furthermore, litigation and other disputes may have a material adverse effect on us because of potential adverse outcomes, defense costs, the diversion of our management’s resources and other risk factors inherent in litigation or relating to the claims that may arise. Our involvement in any litigation matter or other disputes could cause us to incur significant legal and other associated costs, including the payment of damages.

We may not be able to replace expiring or terminated contracts for our existing rigs at dayrates that are economically feasible for us.

Due to the cyclical nature and high level of competition in our industry, we may not be able to replace expiring or terminated contracts. Our ability to replace expiring or terminated contracts will depend on prevailing market conditions, the specific needs of our customers, and numerous other factors beyond our control. Additionally, any contracts for our drilling units may be at dayrates that are below existing dayrates, which could have a material adverse effect on our overall business, financial condition, results of operations and future prospects.

We may suffer losses as a result of foreign currency fluctuations.

A significant portion of the contract revenues of our foreign operations will be paid in USD; however, some payments are made in foreign currencies. As a result, we are exposed to currency fluctuations and exchange rate risks as a result of our foreign operations. To minimize the financial impact of these risks when we are paid in non-U.S. currency, we attempt to match the currency of operating costs with the currency of contract revenue. If we are unable to substantially match the timing and amounts of these payments, any increase in the value of USD in relation to the value of applicable foreign currencies could adversely affect our operating results.

A low amount of, or reduction in, expenditures by oil and gas exploration and production companies, a decrease in demand for oil and gas, or other related factors, could materially and adversely affect our business.

Our business, including the utilization rates and dayrates we achieve for our drilling units, depends on the level of activity in oil and gas exploration, development and production expenditures of our customers. Oil and gas prices and customers’ expectations of potential changes in these prices significantly affect this level of activity. Commodity prices are affected by numerous factors, including the following:

•

changes in global economic conditions;

•

the worldwide supply and demand for oil and gas;

•

the cost of exploring for, producing and delivering oil and gas;

•

expectations regarding future prices;

•

advances in exploration, development and production technology;

•

the ability or willingness of OPEC to set and maintain production levels and pricing;

•

the availability and discovery rate of new oil and gas reserves in offshore areas;

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•

the availability and discovery rate of new oil and gas reserves in the U.S. shale oil and gas regions;

•

the rate of decline of existing and new oil and gas reserves;

•

the level of production in non-OPEC countries, including production levels in the U.S. shale plays;

•

domestic and international tax policies;

•

the development and exploitation of alternative fuels;

•

severe and unpredictable weather conditions;

•

public concern regarding the risks associated with climate change;

•

blowouts and other catastrophic events;

•

governmental laws and regulations, including those aimed at environmental preservation and reductions in carbon emissions;

•

the policies of various governments regarding exploration and development of their oil and gas reserves;

•

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volatility in the exchange rate of USD against other currencies; and

•

the worldwide political environment, uncertainty or instability resulting from an escalation or additional outbreak of armed hostilities or other crises in significant oil and gas producing regions or further acts of terrorism, including volatility in the price of hydrocarbons in connection with Russia’s invasion of Ukraine in February 2022.

In addition to oil and gas prices, the offshore drilling industry is influenced by additional factors, including:

•

the availability of competing offshore drilling vessels and the level of construction activity for new drilling vessels;

•

the consolidation of market participants;

•

the level of costs for associated offshore oilfield and construction services;

•

oil and gas transportation costs;

•

the discovery of new oil and gas reserves;

•

the cost of non-conventional hydrocarbons; and

•

regulatory restrictions on offshore drilling.

Any one of these factors could significantly reduce the demand, or prices paid, for our services and materially and adversely affect our business and results of operations.

The ongoing conflict in Ukraine, including the actual (or perceived threat of an) expansion or exacerbation of such conflict, and the actions undertaken by western nations in response to Russia’s actions, has created, and could continue to create, significant hydrocarbon price volatility and materially impact the global oil and gas markets for the foreseeable future.

At the end of 2021 and in the beginning of 2022, tensions between Russia and members of the North Atlantic Treaty Organization (“NATO”) escalated, and in February 2022, Russia launched a large-scale invasion of Ukraine and Russia and Ukraine continue to engage in active and armed conflict as of March 2022. Such conflict has resulted in significant destruction of Ukraine’s infrastructure and substantial casualties amongst Russian and Ukrainian military personnel. Moreover, civilian casualties have increased significantly as a result of ongoing Russian attacks on cities throughout Ukraine, and the United Nations estimates that the number of refugees fleeing Ukraine to neighboring countries has now exceeded two million. As a result of the invasion, the governments of several western nations, including the U.S., Canada, the United Kingdom and the European Union, implemented several commercial and economic sanctions against Russia, Russian-backed separatist regions in Ukraine, certain banks, companies, government officials, and other individuals in Russia and Belarus. Moreover, on March 9, 2022, President Joe Biden imposed an immediate ban on Russian oil and other energy imports, while the United Kingdom publicly indicated that it would seek to phase out imports from Russia by the end of 2022. Additionally, Canada has now barred Russian vessels from utilizing its ports. In addition to governmental entities, actors in the private sector, including Shell, BP and ExxonMobil, have publicly announced that they intend to stop operations in Russia and cease their partnerships with Russian firms, and shippers, insurance companies and refiners have similarly indicated that they will no longer purchase or ship crude oil from Russia.

The implementation of sanctions by governmental bodies and the withdrawal of private actors in Russia has started to cause, and is likely to continue to cause, among other impacts, significant volatility in the price of hydrocarbons, including constraints on crude oil production. For example, immediately following Russia’s invasion of Ukraine, the Brent oil benchmark increased by approximately 3% reaching approximately $101 per barrel. While the Brent oil benchmark dropped by 13.2% on March 9, 2022 after the United Arab Emirates indicated its support for supplying more oil in the global marketplace, the Brent oil benchmark still settled at approximately $111 per barrel. As market participants seek to limit or flatly ban the use of Russian oil and gas pressure has intensified to seek out alternative fuel sources, and the U.S. has indicated that it may also look to Saudi Arabia to increase its crude oil production.

While it is not possible at this time to predict or determine the ultimate consequences of the conflict in Ukraine, which could include, among other things, additional sanctions, greater regional instability, embargoes, geopolitical shifts and other material and adverse effects on macroeconomic conditions, supply chains, financial markets and currency exchange rates, hydrocarbon price volatility in particular is likely to continue for the foreseeable future. To the extent negotiations of a cease fire between Russia and Ukraine are unsuccessful, the potential destruction of critical oil-related infrastructure in Ukraine, and the implementation of further sanctions and other measures taken by governmental bodies and private actors, could have a lasting impact in the near- and long-term on the (i) business, operations and financial condition of our business and the businesses of our critical counterparties and (ii) the global economy

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at large.

Low prices for oil and gas may reduce demand for our services and could have a material adverse effect on our revenue and profitability.

We are exposed to the credit risks of our key customers and other counterparties that we engage.

We are subject to risks of loss resulting from non-payment or non-performance by third parties. Although we monitor and manage credit risks, some of our customers and other counterparties that we engage may be highly leveraged and subject to their own operating and regulatory risks, as well as other market factors which are not within their direct control. During more challenging market environments, we are subject to an increased risk of our customers and other critical counterparties seeking to, among other things, repudiate or amend their respective contracts and declare force majeure events. The ability of our customers and other critical counterparties to meet their contractual obligations may also be adversely affected by other macroeconomic factors, including constrained credit markets, economic downturns and public health crises. As of December 31, ~~2021~~2022, our allowance for credit losses was $5.0 million. If any of our key customers or other critical counterparties were to default on their contractual obligations owed to us, our business, financial condition, results of operations and cash flows could be materially and adversely affected.

The market value of our current vessels may decrease, which could cause us to take accounting charges or incur losses if we decide to sell them following a decline in their values.

If the offshore contract drilling industry continues to suffer adverse developments, the fair market values of our vessels may decline. The fair market values of the vessels we currently own or may acquire in the future may increase or decrease depending on a number of factors, many of which are beyond our control, including the general economic and market conditions affecting the oil and gas industry and the possible corresponding adverse effect on the level of offshore drilling activity.

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Any such deterioration in the market values of our vessels could require us to record an impairment charge in our financial statements, which could adversely affect our results of operations. If we sell any of our vessels when prices for such vessels have fallen, the sale may be at less than such drillship’s carrying amount on our financial statements, resulting in a loss.

Failure to employ a sufficient number of skilled workers could materially and adversely impact our operations.

The loss of some of our key executive officers and employees could negatively impact our business prospects.

Our future operational performance depends to a significant degree upon the continued service of key members of our management as well as marketing, technical and operations personnel. The loss of one or more of our key personnel could have a material adverse effect on our business. We believe our future success will also depend in large part upon our ability to attract, retain and further motivate highly skilled management, marketing, technical and operations personnel. We may experience intense competition for personnel, and we cannot assure you that we will be able to retain key employees or that we will be successful in attracting, assimilating and retaining personnel in the future.

New technology and/or products may cause us to become less competitive, and higher levels of capital expenditures may be necessary in order to remain competitive.

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The offshore contract drilling industry is subject to the introduction of new drilling techniques and services using new technologies, some of which may be subject to patent protection. As competitors and others use or develop new technologies, we may be placed at a competitive disadvantage. Further, we may face competitive pressure to implement or acquire certain new technologies at a substantial cost. Some of our competitors have greater financial, technical and personnel resources that may enable them to more readily access technological advantages and implement new technologies before we can. We cannot be certain that we will be able to implement new technology or products on a timely basis or at an acceptable cost. Thus, our inability to effectively use and implement new and emerging technology may have a material and adverse effect on our financial condition and results of operations.

Customers may be unable or unwilling to indemnify us.

Consistent with standard industry practice, our customers generally assume liability for and indemnify us against well control and subsurface risks under our dayrate contracts, and we do not separately purchase insurance for such indemnified risks. These risks are those associated with the loss of control of a well, such as blowout or cratering, the cost to regain control or redrill the well and associated pollution. In the future, we may not be able to obtain agreements from customers to indemnify us for such damages and risks or the indemnities that we do obtain may be limited in scope and duration or subject to exceptions. Additionally, even if our customers agree to indemnify us, there can be no assurance that they will necessarily be financially able to indemnify us against all of these risks.

There may be limits to our ability to mobilize drilling units between geographic markets and the time and costs of such drilling unit mobilizations may be material to our business.

The offshore contract drilling market is generally a global market as drilling units may be mobilized from one market to another market. However, geographic markets can, from time to time, have material fluctuations in costs and risks as the ability to mobilize drilling units can be impacted by several factors including, but not limited to, governmental regulation and customs practices, the significant costs to move a drilling unit, availability of tow boats or heavy lift vessels, weather, political instability, civil unrest, military actions and the technical capability of the drilling units to operate in various environments. Any increase in the supply of drilling units in the geographic areas in which we operate, whether through new construction, refurbishment or conversion of drilling units from other uses, remobilization or changes in the law or its application, could increase competition and result in lower dayrates and/or utilization, which would adversely affect our financial position, results of operations and cash flows. Additionally, while a drilling unit is being mobilized from one geographic market to another, we may not be paid by the customer for the time that the drilling unit is out of service. Also, we may mobilize the drilling unit to another geographic market without a customer contract which could result in costs not reimbursable by future customers.

Reactivation of idle rigs may take longer or be more costly than we anticipate.

Reactivation of idle rigs may take longer and be more costly than anticipated. As our rigs are mobilized from one geographic location to another, the labor and other operating and maintenance costs can vary significantly. In general, labor costs increase primarily due to higher salary levels and ~~inflation~~inflationary pressures. Equipment maintenance expenses fluctuate depending upon the type of activity the rig is performing and the age and condition of the equipment. Contract preparation expenses vary based on the scope and length of contract preparation required and the duration of the firm contractual period over which such expenditures are amortized.

Our information technology systems, as well as those of our service and equipment providers and other persons that we engage, are subject to cybersecurity risks and threats.

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We depend on information technology systems that we manage, and others that are managed by our third-party service and equipment providers, to conduct our operations, including critical systems on our drilling units, proprietary and confidential data, financial information, regulated data and personal information of employees and other third parties in the ordinary course of business, and these systems are subject to risks associated with cyber incidents or attacks as well as breaches due to human error. It has been reported that unknown entities or groups have mounted cyberattacks on businesses and other organizations solely to disable or disrupt computer systems, defraud or take financial advantage of companies to disrupt operations and, in some cases, steal data. Due to the nature of cyberattacks, breaches to our systems or the systems of our service or equipment providers could go unnoticed for prolonged periods of time. Successful breaches, employee malfeasance, or human or technological error could result in, amongst other things; unauthorized access to, as well as disclosure, modification, misuse, loss or destruction of, critical company, customer, or other third-party data or systems; loss of revenue, including through inaccurate or unauthorized payments; theft and misappropriation of funds, or sensitive, regulated or confidential or critical data, including personal and company information; the loss of access to critical data or systems through ransomware, phishing attempts, destructive attacks or other means; business delays; and service or system disruptions. Moreover, such cyberattacks could result in higher costs to correct and remedy the effects of such incidents. The Company is also subject to a stringent and ever-changing regulatory environment with respect to privacy and data protection requirements, which could have a material impact on our results of operations. The Audit Committee of our Board of Directors has oversight responsibility related to our cybersecurity risk management programs and periodically reviews reports on cybersecurity and other information technology risks.

In 2018, we experienced a cybersecurity breach which temporarily hindered our ability to utilize our email server and obstructed certain back-up data. However, the breach did not have a material adverse effect on our business, reputation, financial condition, results of operations or cash flows, and did not compromise any customer data. The costs to restore the data and services impacted by the cybersecurity breach were not material. In 2022, we experienced additional e-mail related cybersecurity intrusions (the “2022 Cyber Matters”). We became aware of the 2022 Cyber Matters in the fourth quarter of 2022 and we engaged and have been working alongside a third party forensic specialist to investigate the nature and scope of the incident, implement appropriate technical remediation, and enhance the Company’s cybersecurity to protect against further unauthorized access. Our investigation has revealed that one or more malicious actors gained unauthorized access to certain employees’ business emails. This enabled the malicious actors to fraudulently impersonate certain of the company’s vendors, resulting in (i) two unauthorized transfers of cash from a company bank account to an outside bank account, (ii) one attempted transfer that was stopped and reversed by a financial institution and (iii) one attempted transfer that was stopped by the Company’s internal controls. We have since taken, and continue to take, measures designed to detect, remediate and prevent similar cybersecurity intrusions and threats from recurring. Because the 2022 Cyber Matters are still under investigation, we can neither predict the ultimate outcome of this matter nor whether there will be further developments in the 2022 Cyber Matters investigation that could adversely affect us. Our investigation to date has not revealed any information that suggests the 2022 Cyber Matters will result in a material loss to the Company. However, we are not able to determine the likelihood of loss, if any, arising from this matter. Furthermore, we cannot provide assurance that we will not in the future experience any other actual or attempted breaches of our cybersecurity, or that our security efforts and remedial measures will prevent future security threats from materializing, if at all. If either our systems or the systems of our service or equipment providers used for protecting against cyber incidents or attacks prove to be insufficient and another incident were to occur, it could have a material adverse effect on our business, reputation, financial condition, results of operations or cash flows. Currently, we do not carry insurance for losses related to cybersecurity matters. If we do elect to obtain such coverage in the future, we may incur substantial costs, including in the form of high insurance premiums, especially if we or a third party with which we do business were to fall victim to additional successful cyberattacks or experience any other cybersecurity incidents. Furthermore, in response to the COVID-19 pandemic, many of our office personnel began working remotely in 2020 (and continue to do so through a hybrid work environment), which heightens potential cybersecurity risks given the reliance on remote networking capabilities and utilization of external devices. More recently, Russia’s invasion of Ukraine in February 2022, and the growing tensions between Russia and several western nations, could result in potential retaliatory actions being pursued by Russia and its supporters, including in the form of phishing campaigns, espionage and other forms of cyberattacks. Likewise, pro-Russian ransomware gangs and cyber-criminals have publicly threatened to increase their hacking activities in response to the implementation of sanctions and other actions taken by western countries. If either our systems or the systems of our service or equipment providers used for protecting against cyber incidents or attacks prove to be insufficient and incidents were to occur as a result of working remotely, it could have a material adverse effect on our business, reputation, financial condition, results of operations or cash flows.

Consolidation of suppliers and vendors may increase the costs of obtaining critical supplies and services, which may have a material adverse effect on our results of operations and financial condition.

We rely on certain third parties to provide supplies and services necessary for our offshore drilling operations, including, but not limited to, suppliers and vendors which provide, among other things, drilling equipment, machinery, and catering services. Recent mergers have reduced and consolidated the number of available suppliers and vendors, resulting in fewer alternatives for sourcing key supplies and services. Such consolidation, combined with a high volume of drilling units under construction, could result in a shortage of supplies and services thereby increasing the cost of such supplies and services, and potentially inhibit the ability of suppliers and vendors to deliver on time, if at all. Cost increases and delays in, or the unavailability of, critical supplies and services could have a ~~material and adverse effect on our results of operations and result in drilling unit downtime, and cause, among other things, delays in the repair and maintenance of our drilling units.~~

~~Our information technology systems and those of our service providers are subject to cybersecurity risks and threats.~~32

We depend on information technology systems that we manage, and others that are managed by our third-party service and equipment providers, to conduct our operations, including critical systems on our drilling units, and these systems are subject to risks associated with cyber incidents or attacks as well as breaches due to human error. It has been reported that unknown entities or groups have mounted cyber-attacks on businesses and other organizations solely to disable or disrupt computer systems, disrupt operations and, in some cases, steal data. Due to the nature of cyber-attacks, breaches to our systems or the systems of our service or equipment providers could go unnoticed for a prolonged period of time. These cybersecurity risks could disrupt our operations and result in downtime, loss of revenue or the loss of critical data, as well as result in higher costs to correct and remedy the effects of such incidents. The Audit

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~~Committee~~material ofand adverse effect on our ~~Board~~results of ~~Directors~~operations ~~has~~and ~~oversight~~result ~~responsibility~~in ~~related~~drilling tounit ~~our~~downtime, ~~cybersecurity~~and ~~risk~~cause, ~~management~~among ~~programs~~other ~~and~~things, ~~periodically~~delays ~~reviews~~in ~~reports~~the onrepair ~~cybersecurity~~ and ~~other~~maintenance ~~information~~of ~~technology~~our ~~risks~~drilling units.

In February 2022, Russia launched a large-scale invasion of Ukraine and Russia and Ukraine continue to engage in active and armed conflict as of March 2023. Such conflict has resulted in significant destruction of Ukraine’s infrastructure and substantial casualties amongst Russian and Ukrainian military personnel. Moreover, civilian casualties have increased significantly as a result of ongoing Russian attacks on cities throughout Ukraine, and millions of refugees have fled Ukraine for neighboring countries since the onset of the Russo-Ukraine War. As a result of Russia’s invasion of Ukraine and the ongoing Russo-Ukraine War, the governments of several western nations, including the U.S., Canada, Japan, the United Kingdom and the European Union, implemented several commercial and economic sanctions against Russia, Russian-backed separatist regions in Ukraine, certain banks, companies, government officials, and other individuals in Russia and Belarus. Moreover, on March 9, 2022, President Joe Biden imposed an immediate ban on Russian oil and other energy imports, while the United Kingdom publicly indicated that it would seek to phase out imports from Russia by the end of 2022. In December 2022, the EU imposed an embargo prohibiting the maritime shipment of crude oil from Russia, subject to instituting a price cap of $60-per-barrel. The embargo was also agreed to by the Group of Seven countries and Australia. Additionally, Canada has barred Russian vessels from utilizing its ports. In addition to governmental entities, actors in the private sector, including, among others, Shell, BP and ExxonMobil, have stopped, or publicly announced that they intend to stop, operations in Russia and cease their partnerships with Russian firms, and shippers, insurance companies and refiners have similarly indicated that they will no longer purchase or ship crude oil from Russia.

We may engage in certain strategic or transformational transactions in the future, including acquisitions, dispositions, mergers and joint ventures, any of which could affect the value or type of our assets and overall financial condition.

From time to time, our management independently evaluates, and separately receives indications of interest in respect of, a variety of strategic and/or transformational transactions in respect of our assets or a particular subset thereof. While the documents governing our indebtedness include certain restrictions on our ability to dispose of our assets or to finance the acquisitions of new assets, such restrictions contain various exceptions and limitations.

To the extent we were to pursue or engage in such transactions, including acquisitions and dispositions, there is no guarantee that such transactions will be successful or, even if consummated, improve our operating results and financial condition. We may incur costs, breakage fees or other expenses in connection with any such transactions, and any such transactions may ultimately have a material adverse effect on our operating results and on our ability to pay amounts due on our debt.

In addition, such transactions may be transformative and consequently, may result in a change in the type of the assets we hold and may impact our financial condition. Such new assets may be valued differently as compared to our current assets in the event of a liquidation thereof or due to changes in applicable market conditions even absent such a liquidation scenario. Accordingly, there can be no guarantee that any replacement assets will continue to hold comparable value to our current assets. Likewise, in the event we elect to dispose of revenue-generating assets, it could have a material and adverse impact on our financial condition and overall financial performance. Any such changes to our asset mix, whether by acquisition, disposition or otherwise, may also be viewed negatively by the market and could have an adverse effect on the trading price of our securities.

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Construction projects are subject to risks, including delays and cost overruns, which could have an adverse impact on our liquidity and results of operations.

As part of our existing growth strategy we may contract from time to time for the construction of drilling units or may enter into agreements to manage the construction of drilling units for others. Construction projects are subject to the risks of delay or cost overruns inherent in any large construction project, including costs or delays resulting from the following:

•

unexpected long delivery times for, or shortages of, key equipment, parts and materials;

•

shortages of skilled labor and other shipyard personnel necessary to perform the work;

•

unforeseen increases in the cost of equipment, labor and raw materials, particularly steel;

•

unforeseen design and engineering problems;

•

unanticipated actual or purported change orders;

•

work stoppages;

•

latent damages or deterioration to hull, equipment and machinery in excess of engineering estimates and assumptions;

•

failure or delay of third-party service providers and labor disputes;

•

disputes with shipyards and suppliers;

•

delays and unexpected costs of incorporating parts and materials needed for the completion of projects;

•

financial or other difficulties at shipyards;

•

severe and adverse weather conditions; and

•

inability to obtain required permits or approvals.

If we experience delays and costs overruns in the construction of drilling units due to certain of the factors listed above, it could also adversely affect our business, financial condition and results of operations.

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Negative publicity may adversely affect us.

Media coverage and public statements that insinuate improper actions by us, regardless of their factual accuracy or truthfulness, may result in negative publicity, litigation or governmental investigations by regulators. Addressing negative publicity and any resulting litigation or investigations may distract management, increase costs and divert resources. Negative publicity may have an adverse impact on our reputation and the morale of our employees, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.

The occurrence of any event, change or other circumstance that impedes or delays the ADES Sale could adversely affect our business and financial condition, and there can be no assurance that we will realize the full benefits of the ADES Sale.

Completion of the ADES Sale is subject to several closing conditions and factors outside of our control, any of which could prevent, delay or otherwise adversely affect the consummation of such transaction. Should any of the conditions not be satisfied or waived, it is possible that the ADES Sale could be delayed or impeded and, among other things, the trading price of our securities could be adversely impacted. Furthermore, the failure to consummate the ADES Sale could result in negative publicity and generate a negative impression of us in the marketplace and investment community at large. Failure to complete the ADES Sale would prevent us from realizing its anticipated benefits to our business and, therefore, there can be no assurances that our business, financial condition or operations will not be adversely affected if the ADES Sale is not ultimately consummated. Even if the ADES Sale is ultimately consummated, achieving the anticipated benefits of the ADES Sale is subject to a number of uncertainties, and there can be no assurance that we will realize the full benefits of strategic focus, cost savings and operating efficiencies that we currently expect to be derived from the ADES Sale, if at all, or that these benefits will be achieved within the anticipated time frame.

Because our common stock is not listed on a national securities exchange, it is less liquid and its price may be negatively impacted by factors that are unrelated to, and independent of, our business operations, and therefore, beyond our control. Consequently, there is no assurance that a sufficient market will develop in our common stock, if at all, in which case it could be difficult for shareholders to sell their respective shares of common stock. Even if one or more brokers elects to make a market for our common stock on an over-the-counter market and complies with the applicable regulatory requirements, the market price of our common stock could fluctuate substantially in response to various factors and events, many of which are beyond our control, including the following:

•

a shortfall in rig utilization, operating revenues, or net income from that expected by securities analysts and investors;

•

changes in securities analysts’ estimates of the financial performance of us or our competitors or the financial performance of companies in the oil and gas industry generally;

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changes in actual or market expectations with respect to the amounts of exploration and development spending by oil and gas companies;

•

general conditions in the economy and in energy-related industries;

•

general conditions in the securities markets;

political disturbances, geopolitical instability and tensions, or terrorist attacks, and associated changes in global trade policies and economic sanctions, including, but not limited to, in connection with Russia’s invasion of Ukraine in February 2022;34

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•

political disturbances, geopolitical instability and tensions, or terrorist attacks, and associated changes in global trade policies and economic sanctions, including, but not limited to, in connection with Russia’s invasion of Ukraine in February 2022;

•

the outcome of pending and future legal proceedings, investigations, tax assessments, and other claims to which we are a party or made a party;

•

our completion (or failure to complete) strategic and/or transformational transactions, including acquisitions, dispositions, joint ventures and mergers, as well as the impact of that such transactions may have on our operations and financial condition; and

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fluctuations in the trading volume of our common stock.

There can be no assurances that any public market for our common stock will exist in the future or that we will choose or be able to relist our common stock on a national securities exchange.

Risks Related to Government Regulations and Laws

Political disturbances, geopolitical instability and tensions, or terrorist attacks, and associated changes in global trade policies and economic sanctions could adversely impact our operations.

Our operations are subject to political and economic risks and uncertainties, including instability resulting from civil unrest, political demonstrations, mass strikes, or an escalation or additional outbreak of armed hostilities or other crises including in oil or gas producing areas, which may result in extended business interruptions, suspended operations, volatility in the price of oil and gas, and danger to our employees, or result in claims by our customers of a force majeure situation and payment disputes. Additionally, we are subject to risks of terrorism, piracy, political instability, hostilities, expropriation, confiscation or deprivation of our assets or military action impacting our operations, assets or financial performance in many of our areas of operations.

In particular, the invasion of Ukraine by Russia in February 2022 has led to, and will likely continue to lead to, geopolitical instability, disruption and volatility in the markets in which we operate. It is not possible at this time to predict or determine the ultimate consequences of the conflict in Ukraine, which could include, among other things, additional sanctions, greater regional instability, embargoes, geopolitical shifts and other material and adverse effects on macroeconomic conditions, currency exchange rates, supply chains and financial markets. To the extent negotiations of a cease fire between Russia and Ukraine are unsuccessful, the potential destruction of critical oil-related infrastructure in Ukraine, and the implementation of further sanctions and other measures by governmental bodies and organizations, could have a lasting impact in the near- and long-term on the (i) business, operations and financial condition of our business and the businesses of our critical counterparties and (ii) the global economy at large.

We could be adversely affected by violations of the U.S. Foreign Corrupt Practices Act and similar worldwide anti-bribery laws.

The FCPA and similar worldwide anti-bribery laws (together, anti-corruption laws) prohibit companies and their intermediaries from making improper payments to government officials for the purpose of obtaining or retaining business. Our policies mandate compliance with these laws. We operate in many parts of the world that have experienced governmental corruption to some degree and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local customs and practices. Despite our extensive training and compliance program, we cannot assure you that our internal control policies and procedures will protect us from improper acts committed by our directors, employees or agents. Violations of these laws, or allegations of such violations, could disrupt our business and result in a material adverse effect on our business and operations. We may be subject to competitive disadvantages to the extent that our competitors are able to secure business, licenses or other preferential treatment by making payments to government officials and others in positions of influence or using other methods that U.S. laws and regulations prohibit us from using.

In order to effectively compete in some foreign jurisdictions, we utilize local agents and seek to establish joint ventures with local operators or strategic partners. In addition, in some foreign jurisdictions in which we operate, we are required to retain the services of a national agent or sponsor. Although we have procedures and controls in place to monitor internal and external compliance, if we are found to be liable for violations of anti-corruption laws (either due to our own acts or omissions, or due to the acts or omissions of others, including actions taken by our agents and our strategic or local partners, even though our agents and partners may not be subject to the FCPA), we could suffer from civil and criminal penalties or other sanctions, which could have a material adverse effect on our business, financial position, results of operations and cash flows.

In July 2015, we voluntarily contacted the DOJ and the SEC to advise them that Hamylton Padilha, a Brazilian agent VDC used in the contracting of the Titanium Explorer drillship to Petrobras, had entered into a plea arrangement with Brazilian authorities in connection with his role in facilitating the payment of bribes to former Petrobras executives. In August 2017, we received a letter from the DOJ indicating that it had closed its investigation on the matter without any action, and in November 2018, we concluded a settlement agreement in the amount of $5.0 million with the SEC on a neither-admit-nor-deny basis, formally closing the U.S. government’s ~~investigation for possible violations of the internal accounting control provisions of the FCPA by VDC and its subsidiaries relating to this matter.~~

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investigation for possible violations of the internal accounting control provisions of the FCPA by VDC and its subsidiaries relating to this matter.

We are exposed to potential risks from the requirement that we evaluate our internal controls under Section 404 of the Sarbanes-Oxley Act of 2002.

We have evaluated our internal controls systems in order to allow our management to report on our internal controls, as required by Section 404 of the Sarbanes-Oxley Act of 2002 ("Section 404"). We have performed the system and process evaluation and testing required to comply with the management certification requirements of Section 404. As a result, we have incurred additional expenses ~~and experienced a diversion of management’s time~~. While our management believes we have implemented the requirements relating to internal controls and all other aspects of Section 404 in a timely fashion, we cannot be certain that our internal control over financial reporting will be adequate in the future to ensure compliance with the requirements of the Sarbanes-Oxley Act or the FCPA. If we are not able to maintain adequate internal control over financial reporting, we may be susceptible to sanctions or investigation by regulatory authorities, such as the DOJ and the SEC. Any such action could adversely affect our business operations and financial results.

Our offshore drilling operations could be adversely impacted by changes in regulation of offshore oil and gas exploration and development activity.

Offshore drilling operations could be adversely impacted by changes in regulation of offshore oil and gas exploration and development activities. New regulatory requirements in the future could impose greater costs on our operations, which could have a material adverse impact on our results of operations. We do not currently operate in the United States, but may do so in the future. The jurisdictions in which we currently operate have imposed requirements for offshore oil and gas exploration and development activities and, like the U.S., may impose new regulatory requirements in the future.

Our business is subject to numerous governmental laws and regulations, including those that may impose significant costs and liability on us for environmental and natural resource damages.

Many aspects of our operations are affected by foreign, federal, state and local governmental laws, rules, regulations and policies that may relate directly or indirectly to the contract drilling industry, including those requiring us to control the discharge of oil and other contaminants into the environment or otherwise relating to environmental protection. Countries where we currently operate have environmental laws and regulations covering the discharge of oil and other contaminants and protection of the environment in connection with operations. Operations and activities in the United States and its territorial waters are subject to numerous environmental laws and regulations, including the Clean Water Act, the Oil Pollution Act, the Outer Continental Shelf Lands Act, the Comprehensive Environmental Response, Compensation and Liability Act, the Clean Air Act, the Resource Conservation and Recovery Act and MARPOL. While we do not currently operate in the United States, many of the countries in which we currently operate have similar requirements. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, the denial or revocation of permits or other authorizations and the issuance of injunctions that may limit or prohibit operations.

Laws and regulations protecting the environment have become more stringent in recent years and may in certain circumstances impose strict liability, rendering us liable for environmental and natural resource damages without regard to negligence or fault on our part. These laws and regulations may expose us to liability for the conduct of, or conditions caused by, others or for acts that were in compliance with all applicable laws at the time the acts were performed. The application of these requirements, the modification of existing laws or regulations or the adoption of new laws or regulations relating to exploratory or development drilling for oil and gas could materially limit future contract drilling opportunities or materially increase our costs. In addition, we may be required to make significant capital expenditures to comply with such laws and regulations.

In addition some financial institutions are imposing, as a condition to financing, requirements to comply with additional non-governmental environmental and social standards in connection with operations outside the United States, such as the Equator Principles, a credit risk management framework for determining, assessing and managing environmental and social risk in project finance transactions. Such additional standards could impose significant new costs on us, which may materially and adversely affect us.

Further, certain governments at the international, national, regional and state level are at various stages of considering or implementing treaties and environmental laws that could limit emissions of greenhouse gases, including carbon dioxide, associated with the burning of fossil fuels. It is not possible to predict how new laws to address greenhouse gas emissions would impact our business or that of our customers, but these laws and regulations could impose costs on us or negatively impact the market for offshore drilling services, and consequently, our business.

Changes in laws and regulations of jurisdictions where we operate, including those that may impose significant costs and liability on us for environmental and natural resource damages, may adversely affect our operations. The jurisdictions where we operate have ~~modified or may in the future modify their laws and regulations in a manner that would increase our liability for pollution and other environmental damage.~~

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~~oil~~modified ~~development~~or ~~activities~~may in ~~certain jurisdictions, will be proposed and adopted in~~ the ~~near-term.~~future Onmodify ~~January~~their ~~20,~~laws ~~2021, an executive order was signed directing all executive departments~~ and ~~agencies to immediately commence work to confront the climate crisis, including recommending that the Administrator of the Environmental Protection Agency consider new~~ regulations ~~to establish comprehensive standards of performance and emission guidelines for methane and volatile organic compound emissions from existing operations~~ in the oil and gas sector, including the exploration and production, transmission, processing and storage segments, by September 2021. Moreover, an executive order was signed on January 27, 2021, which, among other things, places the climate crisis at the forefront of the United States’ foreign policy and national security planning, including submitting the United States instrument of acceptance to rejoin the Paris Agreement, affirming the achievement of global reductions of greenhouse gas emissions and net-zero global emissions by 2050 or prior, and reestablishing the United States as a ~~leader~~manner ~~in addressing climate change. Additionally, the executive order provides~~ that, ~~consistent~~would ~~with~~increase ~~applicable~~our ~~law,~~liability the acting Secretary of the Department of the Interior shall pause new oil and gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of U.S. federal oil and gas permitting and leasing practices in light of the Secretary of the Interior’s broad stewardship responsibilities over the public lands and in offshore waters, including potential climate and other impacts associated with oil and gas activities on public lands or in offshore waters. In April 2021, a new target for ~~the United States to achieve a 50 to 52 percent reduction from 2005 levels in economy-wide net greenhouse gas~~ pollution ~~in 2030 was announced,~~ and inother ~~October 2021, as part of the Build Back Better Act, a framework to cut greenhouse gas pollution by over one gigaton in 2030, reduce consumer energy costs and advance~~ environmental ~~justice by investing in a 21st century clean energy economy was also announced~~damage.

With the recent change in administration of the U.S. federal government, it is likely that new legislation, regulatory enforcement actions and executive orders, which are specifically aimed at reducing greenhouse gas emissions, or prohibiting, delaying or restricting oil development activities in certain jurisdictions, will be proposed and adopted in the near-term. On January 20, 2021, an executive order was signed directing all executive departments and agencies to immediately commence work to confront the climate crisis, including recommending that the Administrator of the Environmental Protection Agency consider new regulations to establish comprehensive standards of performance and emission guidelines for methane and volatile organic compound emissions from existing operations in the oil and gas sector, including the exploration and production, transmission, processing and storage segments, by September 2021. Moreover, an executive order was signed on January 27, 2021, which, among other things, places the climate crisis at the forefront of the United States’ foreign policy and national security planning, including submitting the United States instrument of acceptance to rejoin the Paris Agreement, affirming the achievement of global reductions of greenhouse gas emissions and net-zero global emissions by 2050 or prior, and reestablishing the United States as a leader in addressing climate change. Additionally, the executive order provides that, consistent with applicable law, the acting Secretary of the Department of the Interior shall pause new oil and gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of U.S. federal oil and gas permitting and leasing practices in light of the Secretary of the Interior’s broad stewardship responsibilities over the public lands and in offshore waters, including potential climate and other impacts associated with oil and gas activities on public lands or in offshore waters. In April 2021, a new target for the United States to achieve a 50 to 52 percent reduction from 2005 levels in economy-wide net greenhouse gas pollution in 2030 was announced, and in October 2021, as part of the Build Back Better Act, a framework to cut greenhouse gas pollution by over one gigaton in 2030, reduce consumer energy costs and advance environmental justice by investing in a 21st century clean energy economy was also announced.

The execution of the foregoing executive orders and any additional executive orders, as well as the adoption and implementation of any new federal or state legislation or regulations could have a material and adverse impact on our business, financial condition, results of operations and cash flow, including through the creation of increased compliance costs and operating restrictions.

The Economic Substance Act 2021 (as amended) and the Economic Substance Act 2018 (as amended), among other legislation enacted in the Cayman Islands and Bermuda , could materially and adversely affect our operations and financial conditions.

Pursuant to the Economic Substance Act 2021 (as amended) of Cayman Islands and the Economic Substance Act 2018 (as amended) of Bermuda (collectively the “ES Acts”), a registered entity (other than an entity which is resident for tax purposes in certain jurisdictions outside the Cayman Islands or Bermuda) that carries on as a business any one or more of the “relevant activities” referred to in the ES Acts must comply with economic substance requirements. In particular, the ES Acts could require covered entities to maintain an adequate level of qualified employees in the Cayman Islands and/or Bermuda, incur an adequate level of annual expenditure in the Cayman Islands and/or Bermuda, maintain physical offices and premises in the Cayman Islands and/or Bermuda, or perform core income-generating activities in the Cayman Islands and/or Bermuda. The list of “relevant activities” includes carrying on any one (or more) of the following activities: banking; insurance; fund management; financing; leasing; headquarters; shipping; distribution and service centers; intellectual property; and holding entities. The ES Acts could additionally substantially affect the way we operate our business, which could in turn materially and adversely affect our business, financial condition and results of operations.

Because VDI is incorporated under the laws of the Cayman Islands, stakeholders may face difficulties in protecting their interests, and their ability to protect their rights through the U.S. federal courts may be limited.

VDI is an exempted company incorporated with limited liability under the laws of the Cayman Islands. In addition, substantially all of our assets are located outside the United States. As a result, it may be difficult for holders of our securities to effect service of process within the United States upon our directors or executive officers, or enforce judgments obtained in the U.S. courts against our directors or executive officers.

Our corporate affairs are governed by our fourth amended and restated memorandum and articles of association, the Companies Law (as the same may be supplemented or amended from time to time) of the Cayman Islands, and the common law of the Cayman Islands. The rights of holders of our securities to take action against the directors, actions by minority shareholders and the fiduciary responsibilities of our directors under Cayman Islands law are, to a large extent, governed by the common law of the Cayman Islands. The common law of the Cayman Islands is derived in part from comparatively limited judicial precedent in the Cayman Islands as well as from English common law, the decisions of whose courts are of persuasive authority, but are not binding on a court in the Cayman Islands. The rights of our shareholders and the fiduciary responsibilities of our directors under Cayman Islands law are different from those under statutes or judicial precedent in some jurisdictions in the United States. In particular, the Cayman Islands has a different body of securities laws which may provide significantly less protection to investors as compared to the United States, and some states, such as Delaware, which have more fully developed and judicially interpreted bodies of corporate law.

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The Cayman Islands courts are also unlikely:

•

to recognize or enforce against us judgments of courts of the United States based on certain civil liability provisions of U.S. securities laws; and

•

to impose liabilities against us, in original actions brought in the Cayman Islands, based on certain civil liability provisions of U.S. securities laws that are penal in nature.

Additionally, Cayman Islands companies may not have standing to sue before the federal courts of the United States. There is no statutory recognition in the Cayman Islands of judgments obtained in the United States, although the courts of the Cayman Islands recognize and enforce a non-penal judgment of a foreign court of competent jurisdiction without re-examination of the merits of the underlying dispute, provided such judgment:

•

is final;

•

imposes on the judgment debtor a liability to pay a liquidated sum for which the judgment has been given;

•

is not in respect of taxes, a fine, or a penalty; and

•

was neither obtained in a manner, nor is of a kind enforcement of which is contrary to natural justice or the public policy of the Cayman Islands.

The Grand Court of the Cayman Islands may stay proceedings if concurrent proceedings are being brought elsewhere.

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Risks Related to Our Financial Condition and Taxes

We may be required to repurchase certain of our indebtedness with cash upon a change of control or other triggering events.

Upon the occurrence of specified change of control events or certain losses of our vessels in the agreements governing the 9.2550% First Lien Notes, we will be required to offer to repurchase or repay all (or, in the case of events of losses of vessels, an amount up to the amount of proceeds received from such event of loss) of the 9.2550% First Lien Notes at the price and upon the terms set forth in the applicable agreement. In addition, in connection with certain asset sales, we will be required to offer to repurchase or repay the 9.2550% First Lien Notes as set forth in the agreement governing the 9.2550% First Lien Notes. We may not have sufficient funds available to repurchase or repay all of the debt that becomes due and payable pursuant to any such offer, which would constitute an event of default that, in turn, would likely trigger a default under any other then-existing debt agreements. Moreover, the creditors under certain of our debt agreements may limit our ability to repurchase debt. In that event, we would need to refinance the applicable debt, or obtain a waiver under the applicable debt agreement, before making an offer to purchase. We may be unable to refinance such indebtedness or obtain a waiver. See “Risk Factors—We may not be able to make principal or interest payments on our existing and future indebtedness, nor refinance such existing and future indebtedness on favorable terms, if at all, and our inability to make such payments on, or refinance, any such indebtedness could materially and adversely affect our liquidity and results of operations.” Any requirement to offer to repurchase or repay any of our existing debt may therefore require us to refinance some or all of our other outstanding debt, which we may not be able to accomplish on commercially reasonable terms, if at all. These repurchase requirements may also delay or make it more difficult for others to obtain control of us.

We have identified material weaknesses in our internal control over financial reporting.

We have identified a material weakness in our internal control over financial reporting related to the prevention of unauthorized cash disbursements (see “Risk Factors—Our information technology systems, as well as those of our service and equipment providers and other persons that we engage, are subject to cybersecurity risks and threats.”). The Company’s internal control over financial reporting has been designed to provide management and the Board of Directors with reasonable assurance regarding the preparation and fair presentation of the Company’s consolidated financial statements. However, internal controls governing the process for updating vendor information were not adequate to safeguard the company’s cash assets from unauthorized transfers resulting from the lack of a policy requiring multiple confirmations with respect to changes to vendor information.

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We believe that our overall internal control environment is sufficient for a company of our size. However, the existence of a material weakness means that there is a reasonable possibility that a material misstatement of our financial statements will not be prevented or detected on a timely basis. If we are not able to correct material weaknesses or deficiencies in internal controls in a timely way, our ability to record, process, summarize and report financial information accurately and within the time periods specified in the SEC’s rules and forms will be adversely affected. Such a result could negatively impact the market price and trading liquidity of our stock, weaken investor confidence in our reported financial information, subject us to civil and criminal investigations and penalties, and generally materially and adversely affect our business and financial condition. For more information regarding the material weakness, the mitigating controls we use, and certain remedial steps we have taken or considered, please see Part II. Item 9A Controls and Procedures.

Material and adverse developments impacting the financial services industry at large, including the occurrence of actual (or widespread concerns regarding the potential occurrence of) defaults, illiquidity, operational failures and non-performance by financial institutions and critical counterparties, could have a material and adverse effect on our business, financial condition and results of operations.

The occurrence of actual (or widespread concerns regarding the potential occurrence of) illiquidity, operational failures, defaults, non-performance or other material and adverse developments that impact financial institutions and transactional counterparties, or other entities within the financial services industry at large, have previously caused, and could continue to cause, market-wide liquidity issues, bank-runs and general contagion across the global financial industry. For example, on March 10, 2023, Silicon Valley Bank (“SVB”) was closed by the California Department of Financial Protection and Innovation and the Federal Deposit Insurance Corporation (the “FDIC”) was subsequently appointed as a receiver. Similarly, on March 12, 2023, Signature Bank and Silvergate Capital Corp. were each placed into receivership. While the U.S. Federal Reserve Board, the FDIC and the U.S. Department of Treasury collectively agreed to guarantee all deposits, above and beyond the limit on insured deposits of $250,000 at these financial institutions, there can be no assurance that there will not be additional bank failures or issues in the broader financial system. Likewise, there is no guarantee that any of the U.S. Department of Treasury, the FDIC or the Federal Reserve Board will provide access to any additional uninsured funds in the future in the event of the closure or failure of any other banks or financial institutions, or that they would do so promptly or in a timely fashion. Additionally, substantial and rapid increases in interest rates and inflation have led to a decline in the trading value of previously issued government securities with interest rates below current market interest rates. While the U.S. Department of Treasury, Federal Reserve Board and the FDIC have announced a program to provide up to $25 billion of loans to financial institutions secured by certain of such government securities held by financial institutions to mitigate the risk of potential losses on the sale of such instruments, the liquidity needs of financial institutions, including as a result of widespread demands for customer withdrawals, may exceed the capacity of such program.

Furthermore, we and other parties with who we conduct business and engage commercially may be unable to access critical funds in deposit accounts or other accounts held with a closed or failing financial institution or pursuant to lending arrangements with such financial institutions. Accordingly, in such instance, our ability to pay our obligations, and any of our counterparties’ ability to pay their respective obligations, or enter into new commercial arrangements requiring additional payments, could be materially and adversely affected.

Our current backlog of contract drilling revenue may not be fully realized, which may have a material adverse impact on our consolidated statement of financial position, results of operations or cash flows.

As of December 31, ~~2021~~2022, our owned fleet had total drilling contract backlog of approximately $~~398~~217.2 million, ~~including~~(includes $~~190~~61.82 million ~~related~~for torigs ~~the~~owned ~~EDC~~by ~~sale~~third ~~which~~parties iswhere ~~the~~we ~~owner~~enter ofinto ~~the~~contracts ~~Emerald~~directly ~~Driller,~~with ~~Sapphire~~customers ~~Driller~~ and ~~Aquamarine~~lease ~~Driller,~~the ~~which~~rigs ~~are~~through ~~classified~~bareboat ascharters ~~held~~from ~~for~~the ~~sale~~rig onowners. The ~~our~~terms ~~Consolidated~~of ~~Balance~~the ~~Sheets~~bareboat ~~(see~~charters ~~"Recent~~are ~~Developments~~consistent -with ~~Share~~the ~~Purchase~~management ~~Agreement~~agreements, toresulting ~~Sell~~in ~~EDC~~the tosame ~~ADES~~financial ~~Arabia~~impact ~~Holding~~to ~~and~~us ~~Entry~~had ~~into~~ the ~~ADES~~rigs ~~Global~~remained ~~Strategic~~under ~~Alliance"~~the inmanagement ~~Part I, Item 1 for additional information)~~agreements. ) This amount was calculated based on certain estimates and assumptions regarding operations and payments to be received under such drilling contracts. Although management believes that such estimates and assumptions are reasonable, actual amounts received under these contracts could materially differ from the projected amount. Material differences between the projected contract backlog amount and the amounts actually received pursuant to such contracts could be caused by a number of factors, including rig downtime or suspension of operations. We may not be able to realize the full amount of our contract backlog due to events beyond our control.

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We have experienced, and could continue to experience, a lack of profitable operations in the near- and long-term.

We have recently experienced, and could continue to experience, operational losses, which may negatively impact our ability to achieve our business objectives and profitability. Specifically, we incurred a net loss of $~~110~~3.14 million and $~~276~~110.71 million for the years ended December 31, ~~2021~~2022 and ~~2020~~2021, respectively, and we experienced negative cash flow from operations. We can provide no assurance that we can achieve profitability or sustain cash flow positive operations on a quarterly or annual basis in the near- or long-term. Moreover, our business and results of operations have been, and could continue to be, negatively impacted by general economic and other market conditions in the industry in which we operate, many of which are out of our control. Declines in the demand for our contract drilling services and dayrates for the services we provide, and any protracted downturn in the oil and gas industry, could have a material and adverse effect on our ability to achieve profitable operations and exacerbate other risks which impact our financial condition, results of operations and cash flow.

Our financial results may not reflect historical trends.

Our past financial performance may not be indicative of our future financial performance. We have a limited operating history since our emergence from bankruptcy on the Effective Date. Further, we became a new entity for financial reporting purposes when we adopted fresh-start accounting as of our emergence from bankruptcy. As a result, our financial results for periods following our emergence from bankruptcy are different from historical trends and the differences may be material.

Changes in tax laws, treaties or regulations, effective tax rates or adverse outcomes resulting from examination of our tax returns could adversely affect our financial results.

Our future effective tax rates could be adversely affected by changes in tax laws, treaties, and regulations both internationally and domestically. Tax laws, treaties and regulations are highly complex and subject to interpretation. Our income tax expense is based upon the interpretation of the tax laws in effect in various countries at the time that the expense was incurred. A change in these 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 worldwide earnings.

Our consolidated effective income tax rate is impacted by a mix between our domestic and international pretax earnings or losses, as well as the mix of the international tax jurisdictions in which we operate. The extent of the impact cannot be anticipated due to the uncertainty regarding the nature and extent of our business activities in any particular jurisdiction in the future and the tax laws of such jurisdictions. For example, in recent years we observed a global trend, in various jurisdictions, of enacted and proposed laws and regulations which aim to limit deductions, deny treaty benefits and /or impose additional taxes; all of these efforts are aligned with the base erosion and profit shifting framework. Should we operate in any of the locations where this trend is ongoing, our financial position and business operations may be adversely impacted.

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jurisdictions. For example, in recent years we observed a global trend, in various jurisdictions, of enacted and proposed laws and regulations which aim to limit deductions, deny treaty benefits and /or impose additional taxes; all of these efforts are aligned with the base erosion and profit shifting framework. Should we operate in any of the locations where this trend is ongoing, our financial position and business operations may be adversely impacted.

A loss of a tax dispute or a successful tax challenge to our operating structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries could result in a higher tax rate on our worldwide earnings, which could in turn result in a material adverse effect on our financial condition and results of operations.

Income tax returns that we file will be subject to review and examination. We recognize the benefit of income tax positions we believe are more likely than not to be sustained upon challenge by a tax authority. If any tax authority successfully challenges our operational structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries, if the terms of certain tax treaties are interpreted in a manner that is adverse to our structure, or if we lose a material tax dispute in any jurisdiction, our effective tax rate on our worldwide earnings could increase substantially and result in a material adverse effect on our financial condition.

U.S. Holders will be required to pay U.S. taxes on their share of VDI’s income even if they do not receive any cash distributions from VDI.

Because VDI is treated as a partnership for U.S. federal income tax purposes, U.S. Holders will be required to pay U.S. federal income taxes and, in some cases, U.S. state and local income taxes on their share of VDI’s taxable income. Given VDI’s current structure as a holding entity with no direct operations at the VDI level, we do not currently expect to generate material positive taxable income at VDI in the near term. However, to the extent VDI does generate positive taxable income, U.S. Holders would still be required to pay U.S. taxes on their share of said income regardless of whether or not we make corresponding distributions to our equity holders. In addition, we cannot assure you that our current structure will not change in the future. U.S. Holders may not receive cash distributions from VDI equal to their share of VDI’s taxable income or even equal to the actual tax liability that results from their share of VDI’s taxable income.

An entity that would otherwise be classified as a partnership for U.S. federal income tax purposes may, unless an exception applies, nonetheless be taxable as a corporation if it is a “publicly traded partnership.” An entity that would otherwise be classified as a partnership is a publicly traded partnership if (1) interests in the partnership are traded on an established securities market or (2) interests in the partnership are readily tradable on a secondary market or the substantial equivalent thereof. It is likely that VDI will be treated as a “publicly traded partnership.” However, an exception to taxation as a corporation, referred to as the “Qualifying Income Exception,” exists if at least 90% of such partnership’s gross income for every taxable year consists of “qualifying income” and the partnership is not required to register under the Investment Company Act. Qualifying income includes certain interest income, dividends, real property rents, gains from the sale or other disposition of real property, and any gain from the sale or disposition of a capital asset or other property held for the production of income that otherwise constitutes qualifying income. VDI believes that it currently meets, and expects that it will continue to meet, the Qualifying Income Exception.

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Distributions made by VDI may reduce a U.S. Holder’s tax basis in the Ordinary Shares, and therefore, U.S. Holders may realize a greater gain on the disposition of their Ordinary Shares than they otherwise may expect, and may have a tax gain even if the price they receive in a disposition of their Ordinary Shares is less than their original tax basis.

If U.S. Holders sell their Ordinary Shares, they will recognize gain or loss for U.S. federal income tax purposes that is equal to the difference between the amount realized and their tax basis in those Ordinary Shares. Prior distributions in excess of the total net taxable income allocated decrease a U.S. Holder’s tax basis and will, in effect, become taxable income if Ordinary Shares are sold at a price greater than their tax basis, even if the price received is less than the U.S. Holder’s original tax basis. Future cash distributions that exceed the U.S. Holder’s tax basis would result in a gain for U.S. federal income tax purposes.

In the case of a disposition of our Ordinary Shares, VDI’s debt must be taken into account under the partnership tax accounting rules.

From time to time, VDI may incur debt for a variety of reasons. Under partnership tax accounting principles, VDI’s debt will generally be allocable to holders of VDI’s Ordinary Shares, and the holders will include their respective allocable shares of the debt in the U.S. federal income tax basis of their Ordinary Shares. A holder’s U.S. federal income tax basis in VDI’s Ordinary Shares will be adjusted for, among other things, distributions of cash, if any, and allocations of items of VDI’s income, gain, loss and deduction. At the time a U.S. Holder of VDI’s Ordinary Shares later sells its Ordinary Shares, for U.S. federal income tax purposes, the U.S. Holder’s amount realized on the sale will include not only the sales price of the Ordinary Shares but also the U.S. Holder’s portion of VDI’s indebtedness that is allocable to those Ordinary Shares.

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U.S. tax-exempt holders and non-U.S. Holders face unique U.S. tax issues from owning Ordinary Shares that may result in adverse U.S. tax consequences to them.

Organizations exempt from U.S. federal income tax under Section 501(a) of the Code are subject to tax on “unrelated business taxable income” (“UBTI”). UBTI arises primarily as income from an unrelated trade or business regularly carried on or as income from “debt-financed” property. U.S. tax-exempt holders of Ordinary Shares generally would be subject to tax on their allocable shares of UBTI realized by VDI in the same manner as if such UBTI were realized directly by such organizations. Debt-financed property means property held to produce income with respect to which there is “acquisition indebtedness” (i.e., indebtedness incurred in acquiring or holding property). As VDI has incurred “acquisition indebtedness” (such as, for example, the 9.25% ~~Senior~~First ~~Secured~~Lien Notes and the 9.50% First Lien Notes), U.S. tax-exempt holders of Ordinary Shares may be subject to the tax on UBTI on their investment (for so long as VDI is treated as a partnership for U.S. federal income tax purposes and has acquisition indebtedness).

VDI expects to conduct its affairs so that it will not be treated as engaged in a trade or business within the U.S. for U.S. federal income tax purposes. As a consequence, VDI expects that (i) non-U.S. Holders will not be subject to U.S. federal tax on a net income basis with respect to the income of VDI, and (ii) VDI will not be required to withhold tax under Section 1446 of the Code with respect to non-U.S. Holders. If, however, VDI were determined to be engaged in a trade or business within the United States for U.S. federal income tax purposes, and had income effectively connected therewith, then, in the case of a non-U.S. Holder; (a) the share of VDI’s income that is effectively connected with such trade or business that is allocable to such non-U.S. Holder could be subject to U.S. federal income withholding tax at a rate equal to the highest applicable U.S. federal income tax rate and such holder could be required to file a U.S. federal income tax return and pay U.S. federal income tax on its allocable share of VDI’s net effectively connected income; (b) all or a portion of the gain on the disposition (including by redemption) of Ordinary Shares by such non-U.S. Holder could be taxed as effectively connected income to the extent such gain is attributable to assets of VDI that generate effectively connected income; (c) if such non-U.S. Holder is a corporation, such income could be subject to an additional branch profits tax of 30% on its allocable share of VDI’s effectively connected earnings and profits, adjusted as provided by law (subject to reduction by any applicable tax treaty); and (d) such non-U.S. Holder, whether or not a corporation, could be viewed as being engaged in a trade or business within the United States and as maintaining an office or other fixed place of business within the United States, and certain other income of such non-U.S. Holder could be treated as effectively connected income (for example, a non-U.S. Holder who, pursuant to an applicable tax treaty, is currently not subject to tax with respect to a trade or business within the United States because such holder does not have a permanent establishment in the United States could lose the benefits of the tax treaty as a result of its ownership of Ordinary Shares).

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Item 1B. Unresolved Staff Comments.

None.

Item 2. Properties.

We maintain offices, land bases and other facilities in several worldwide locations, including our principal executive offices in Houston, Texas, an operational, executive and marketing office in Dubai and a regional administrative office in Singapore. We lease all of these facilities.

The description of our drilling fleet included under “Business” in Part I, Item 1 of this Annual Report is incorporated by reference in its entirety into this Part I, Item 2.

Item 3. Legal Proceedings.

Information regarding the Company’s legal proceedings is set forth in “Note 8. Commitments and Contingencies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report. The information discussed therein is incorporated by reference in its entirety into this Part I, Item 3.

Item 4. Mine Safety Disclosures.

Not applicable.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Market Prices and Distributions

Since February 2020, our Ordinary Shares have been quoted on the OTC Pink Open Market under the symbol “VTDRF.” Any over-the-counter market quotations reflect inter-dealer prices, without retail mark-up, markdown or commission and may not necessarily represent actual transactions. The following chart lists the range of high and low closing bid prices for shares of the Company’s common stock for each quarterly period within the last two fiscal years.

	High Bid		Low Bid
Fiscal Year 2020:
First Quarter		32.00		12.00
Second Quarter		13.50		5.95
Third Quarter		11.00		1.25
Fourth Quarter		3.25		1.00
Fiscal Year 2021:
First Quarter		4.00		1.26
Second Quarter		3.50		2.00
Third Quarter		4.25		2.25
Fourth Quarter		5.90		2.70
Fiscal Year 2022:
First Quarter		11.02		5.55
Second Quarter		18.00		9.20
Third Quarter		17.50		13.00
Fourth Quarter		18.00		14.20

Many of our shareholders hold shares electronically, all of which are owned by a nominee of DTC. As of March 713, ~~2022~~2023, there were approximately ~~151~~155 holders of record of our Ordinary Shares.

The Board of Directors declared the Special Cash Distribution to shareholders of record as of the close of business on December 10, 2019.

Other than the Special Cash Distribution, we have not made any cash or other distributions in respect of our New Shares to date and do not anticipate paying cash distributions in the immediate future as we contemplate that our cash flows will be used for debt reduction and growth. The payment of future distributions, if any, will be determined by the Board of Directors in light of the conditions then existing, including our earnings, financial condition, capital requirements, restrictions in financing agreements, business conditions and other factors. We are subject to certain restrictive covenants under the terms of the agreements governing our indebtedness, including restrictions on our ability to pay any cash distributions.

Repurchases of Equity Securities

The ability to make share repurchases is subject to, among other things, the discretion of our Board of Directors and the covenants in our credit agreement. There are no share repurchase programs outstanding at December 31, ~~2021~~2022.

There were no repurchases of equity securities during the fiscal fourth quarter ended December 31, ~~2021~~2022.

Information regarding the Company’s shares available for issuance in connection with equity compensation plans is set forth in “Note 6. Shareholders' Equity” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report. The information discussed therein is incorporated by reference in its entirety into this Part II, Item 5

Item 6. Reserved

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion is intended to assist you in understanding our financial position and our results of operations for the years ended December 31, ~~2021~~2022, ~~2020~~2021 and ~~2019~~2020. The following discussion should be read in conjunction with the information contained in “Item 1. Business,” “Item 1A. Risk Factors” in Part I of this Annual Report and “Item 8. Financial Statements and Supplementary Data” in Part II of this Annual Report. Certain previously reported amounts have been reclassified to conform to the current year presentation.

Overview

We are an international offshore drilling company focused on operating a fleet of modern, high specification drilling units. Our principal business is to contract drilling units, related equipment and work crews, primarily on a dayrate basis to drill oil and gas wells

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for our customers. Through our fleet of drilling units we are a provider of offshore contract drilling services to major, national and independent oil and gas companies, focused on international markets. Additionally, for drilling units owned by others, we provide operational and marketing services for operating and stacked rigs, construction supervision services for rigs that are under construction and preservation management services for rigs that are stacked.

The following table sets forth certain information concerning our owned, managed and supported offshore drilling fleet as of March 2513, ~~2022~~2023:

Name	Year Built	Water DepthRating (feet)		Drilling DepthCapacity(feet)		Location	Status
Jackups (2)
Owned Rigs:
Topaz Driller	2009		375		30,000	Tunisia	Operating
Jackups
Soehanah	2007		375		30,000	Thailand	Operating
Topaz Driller	2009		375		30,000	Egypt	Operating
Soehanah	2007		375		30,000	Indonesia	Operating
Drillships (1)
Platinum Explorer	2010		12,000		40,000	India	Operating
Tungsten Explorer	2013		12,000		40,000	~~Egypt~~Namibia	Operating
Third Party Owned Rigs:
Drillships
Polaris	2008		10,000		37,500	India	Operating
Aquarius	2008		10,000		35,000	Spain	Warm stacked
Capella	2008		10,000		37,500	Labuan	Mobilizing
Jackups
Emerald Driller	2008		375		30,000	Qatar	Operating
Sapphire Driller	2009		375		30,000	Qatar	Operating
Aquamarine Driller	2009		375		30,000	Qatar	Operating

(1)

The drillships are designed to drill in up to 12,000 feet of water and are currently equipped to drill in 10,000 feet of water.

On December 20, 2021, we entered into the ADES Purchase Agreement (as defined below in Part II, Item 8 under "Organization and Recent Events" of this Annual Report) to sell EDC which owns the Emerald Driller, Sapphire Driller and Aquamarine Driller. These rigs are currently classified as held for sale on our Consolidated Balance Sheets as of December 31, 2021.

Business Outlook

Expectations about future oil and gas prices have historically been a key driver of demand for our services. Over ~~Against~~ the ~~backdrop~~past of18 ~~challenging industry conditions which began in 2015~~months, ~~the initial onset, and continued~~ global ~~spread~~oil ofprices ~~the~~have ~~COVID-19~~experienced ~~pandemic~~a ~~and~~robust ~~the~~recovery resulting ~~decline~~ in ~~global economic activity, coupled with~~ the ~~short-lived~~strongest ~~price~~annual ~~war~~performance ~~between Saudi Arabia and Russia, led to significant reductions and delays in oil and gas exploration and development plans~~ (on ~~the part of operators during 2020, largely impeding and unwinding the improvements experienced by the industry in 2019. These reductions and delays led to~~ a ~~substantial~~price-per-barrel ~~drop~~basis) insince ~~oil prices and demand for offshore drilling services globally, including for our services, during, and subsequent to, the second quarter of 2020~~2012. ~~However~~During 2022, asspecifically aBrent ~~whole,~~crude ~~global~~ oil ~~prices~~reached ~~experienced~~ a ~~strong~~high ~~recovery~~of ~~during~~approximately ~~2021~~$125.00 ~~resulting~~per inbarrel ~~the best yearly performance~~ in aMarch ~~decade,~~2022; ~~with~~although Brent crude ~~oil~~ultimately ~~trading~~settled ~~close~~at toapproximately $85.00 per barrel inon ~~October~~the ~~2021~~last ~~and~~day ~~more~~of ~~recently~~ trading ~~above $115.00 per barrel~~ in ~~March~~December 2022. ~~This~~The ~~strong~~relatively ~~recovery~~elevated isprices exhibited in 2022 were due to, among other factors, the (i) OPEC+ countries’ agreement ~~since~~in ~~last~~2020 ~~year~~ to reduce production by almost 10 million barrels per day, representing approximately 10% of the world's output compared with demand for approximately 96 million barrels a day, and their recent agreement to boost production, but only in measured steps, (ii) development, efficacy, availability and utilization of vaccines for COVID-19, (iii) the reopening of global economies, (iv) injection of substantial government monetary and fiscal stimulus and (v) the ongoing energy supply crisis driven by a shortage of fuel within recovering economies and anticipated extreme weather across Europe and northeast Asia, along with years of under investment in oil reserve replacement all of which has been exacerbated by ~~the~~ global turmoil, and political and market instability caused by ~~Russia's~~the ~~invasion~~Russo-Ukrainian ~~of Ukraine in February 2022~~War.

Notwithstanding the ~~foregoing,~~elevated ~~the~~prices ~~volatility~~of ~~and uncertainty surrounding global~~ oil ~~prices~~exhibited ~~largely~~during ~~remain as~~ the ~~spread~~prior of18-month ~~the~~period, ~~COVID-19~~market ~~pandemic~~volatility and ~~its~~uncertainty ~~highly~~largely ~~transmissible~~remain ~~variants persist~~ and, ~~as a whole,~~ the oil and gas industry continues to be materially impacted and shaped by external factors which have influenced its overall development and recovery~~. While~~, ~~OPEC+~~including ~~countries~~global ~~entered~~macroeconomic ~~into~~challenges anresulting ~~agreement~~from ininflationary ~~July~~pressures ~~2021~~and topotential ~~gradually~~recessionary ~~phase~~conditions, ~~out~~as ~~certain~~well ~~oil~~as ~~production~~geopolitical ~~cuts~~and market instability caused by ~~September~~the ~~2022~~Russo-Ukrainian ~~and~~War. In ~~subsequently~~response ~~acknowledged~~to ~~that~~these itchallenges, ~~would~~OPEC+ ~~continue~~agreed toon ~~observe~~October ~~such~~5, ~~agreement~~2022 to ~~only~~a ~~boost~~ production ~~modestly~~cut ~~despite~~of ~~higher~~two ~~oil~~million ~~prices~~barrels per day, ~~the~~an ~~long-term~~amount ~~commitment~~which constitutes approximately 2.0% of ~~such~~overall ~~countries~~global oil production. While the U.S. intends to ~~maintain~~release additional barrels from its strategic oil reserve in response to these production atcuts, orthe ~~near~~actions ~~such~~taken ~~levels~~by ~~remains~~OPEC+ ~~uncertain.~~could ~~More~~contribute ~~recently~~to, ~~the~~among ~~ongoing~~other ~~conflict~~things, greater inflationary pressures and sharp price increases to oil and gas in ~~Ukraine~~the near- and long-term. Moreover, the Russo-Ukrainian War has caused, and could continue to cause for the foreseeable future, significant instability, disruption, uncertainty and volatility in the hydrocarbon industry and the global markets at large. Further geopolitical developments could occur, including a possible agreement relating to Iran’s nuclear deal and the subsequent suspension of U.S. sanctions in Iran (which could result in, among other things, the influx of Iranian crude oil into the global markets), any of which could significantly impact our business and operations. With Ashigher acrude ~~result~~oil ofprices ~~such~~there ~~volatility,~~is ~~disruption,~~the ~~instability~~potential ~~and~~for ~~uncertainty,~~increased itproduction ~~has~~from ~~been~~U.S. ~~difficult,~~shale producers and ~~will~~non-OPEC ~~generally~~countries, ~~continue~~which could lead to besignificant ~~difficult,~~increases ~~for~~in ~~operators~~the tooverall ~~definitively~~global ~~plan~~oil ~~their~~and ~~capital~~gas ~~budget~~supply, ~~programs~~and result in ~~the~~reduced ~~near~~commodity ~~term~~prices.

In addition ~~to macroeconomic challenges~~, ~~including~~the ~~those~~opening ~~set~~of ~~forth above~~economies, ~~which~~supply ~~have~~chain ~~led~~constraints toand ~~reduced~~limitations ~~demand~~occurring ~~for~~throughout ~~drilling rigs,~~ the ~~excess~~world ~~supply~~and ofacross ~~delivered~~various industries, and ~~new-build~~the ~~rigs~~injection ~~continues~~of tosignificant ~~impact~~levels ~~overall~~of ~~market~~governmental ~~demand. It~~monetary isand ~~unclear~~fiscal ~~when~~stimulus ~~these~~to ~~new-build~~avoid ~~drilling~~a ~~rigs~~recession ~~will~~during ~~actually~~the bepeak ~~delivered,~~of ifthe atCOVID-19 ~~all~~pandemic, ascollectively ~~many~~contributed ~~rig~~to ~~deliveries~~the ~~have~~highest ~~(i)~~level ~~already~~of ~~been~~inflation ~~deferred~~in todecades ~~later~~across ~~dates~~the orU.S., ~~(ii)~~the ~~been~~United ~~canceled~~Kingdom, ~~entirely.~~

In response to the oversupply of drilling rigs, a number of our competitors have removed older, less competitive rigs from their fleets by cold stacking the drilling rigs, repurposing rigs for use in other industries or taking them permanently out of service. A substantial number of rigs have been removed from the drilling fleet since the oil price decline in 2014 and this trend has only accelerated since the second quarter of 2020. However, we have recently observed instances where cold-stacked rigs are being reactivated for new 44

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~~contracts~~Europe asand the ~~supply~~global ofcommunity ~~ready~~at large. In the U.S., for example, the Consumer Price Index reached a 40-year high in June 2022. While such rates are expected to ease incrementally in the near-goterm, ~~rigs~~our ~~diminishes. This~~operations could ~~result~~be materially and adversely impacted by any exacerbation to global inflation, including in ~~more~~the form of increases in personnel costs and the prices of goods and services required to operate our rigs. ~~competing~~Given that we enter into fixed dayrate contracts that have contractual terms with usminimal inadjustments ~~the~~to ~~market~~account for rising inflation, ~~and~~the inmajority ~~turn~~(if ~~cause~~not ~~dayrates~~all) of these costs would be borne by us. While we are currently unable to ~~remain~~estimate ~~under~~the ~~pressure~~ultimate impact of inflation, ~~which~~including ~~may~~the associated impact on the ~~environment~~prices of goods and services, our costs could rise in ~~which~~the wenear-term ~~compete~~and materially impact our profitability and overall financial condition.

InFurthermore, ~~addition~~central ~~many~~banks ~~offshore~~and ~~drillers~~regulators ~~with~~across ~~significant~~the ~~levels~~world ~~of debt on their balance sheets~~ have ~~recently completed~~raised, ~~are~~and ~~currently~~they ~~pursuing,~~could orcontinue ~~may elect~~ to ~~pursue in the near-term~~raise, ~~debt~~interest ~~restructurings. As~~rates ~~drillers~~in ~~emerged~~an ~~and~~attempt ~~continue~~ to ~~emerge~~gain ~~from~~further ~~these~~control ~~debt~~over ~~restructurings,~~and ~~consolidation~~reduce inflation in ~~the~~their ~~industry~~respective ~~transpired~~jurisdictions. Such ~~and~~efforts itbeing isundertaken ~~likely~~by ~~that~~central ~~further~~banks ~~consolidation~~and ~~will~~regulators ~~occur,~~could ~~reducing~~tip the ~~number~~global ofeconomy ~~industry~~into ~~participants~~a ~~and~~recession, ~~ultimately~~which ~~lowering~~could ~~cost~~materially ~~structures. The combination of recycling, restructuring~~ and ~~consolidation~~adversely ~~will~~impact bedemand ~~necessary~~ for ~~the~~oil ~~industry~~and togas ~~regain firmer footing. Any industry recovery will also depend significantly on continued~~ and, ~~demonstrable improvement~~ in ~~global macroeconomic conditions including~~ the ~~ability~~process, todemand ~~mitigate~~for ~~COVID-19's~~our ~~highly contagious variants and mutations~~services.

InAs ~~response~~a toresult ~~both market conditions and excessive levels~~ of ~~idle~~such ~~capacity~~volatility, ~~in recent years~~disruption, ~~there~~instability ~~has been intense downward pressure on operating dayrates since 2015 as most drilling contractors had preferred to maintain rigs in an active state to mitigate the risks~~ and ~~costs~~uncertainty, ofoperators ~~stacking~~have ~~and~~faced, ~~reactivating rigs~~ and towill ~~benefit from the fact that customers had~~ generally ~~favored~~continue ~~operating rigs over reactivated cold-stacked rigs. Prior~~ to ~~the COVID-19 pandemic~~face, ~~this~~difficulties ~~downward~~when ~~pressure~~attempting ~~on pricing was starting~~ to ~~reverse~~definitively ~~itself~~plan astheir ~~evidenced~~capital bybudget ~~increased~~programs ~~demand~~ for ~~our services in 2019 and early 2020, and dayrates were showing signs of general improvement. However, beginning in~~ the ~~second~~near- ~~quarter of 2020, with the initial onset, continued spread,~~ and ~~resulting impact of the COVID~~long-19 ~~pandemic, dayrates, rig activity and contract opportunities each came under significant pressure again~~term. ~~Dayrates began showing signs of improvement during 2021, resembling pricing trends exhibited prior to the onset of COVID-19.~~

With the distribution of vaccines in certain jurisdictions in an attempt to inoculate populations against COVID-19 along with significant governmental assistance directed at combatting the challenging economic environment caused by the COVID-19 pandemic, economic activity in certain portions of the world generally improved during 2021. This improvement has contributed to, among other things, a general increase in the demand for oil and gas. Since dropping to multi-year lows in the second quarter of 2020, Brent crude oil prices as a whole reached healthier levels in 2021 as compared to 2020. As a result, the jackup segment experienced visible recovery in 2021 with respect to utilization rates and the deepwater segment has started to exhibit signs of near- to medium-term recovery regarding utilization rates. The bifurcation of this recovery timing may be due, in part, to the fact that a significant amount of time transpires between the date a final investment decision is made with regard to a deepwater project and the date upon which the program activity actually commences, and any uncertainty regarding the direction of oil prices and rate of recovery could weigh significantly on these decisions. However, to the extent that global economic activity continues to improve or is, at a minimum, sustained at its current levels, operators could begin to sanction new activity, which could lead to more rigs going back on contracts and potentially higher dayrates.

Notwithstanding the foregoing, any recovery experienced could be short lived especially given the quickly changing and ever-evolving dynamics of the COVID-19 pandemic and its highly transmittable variants and sub-lineages. With the COVID-19 pandemic unlikely to completely subside in the near term, the possibility exists that the world will need to continue to learn to operate in and further adapt to the current environment for the foreseeable future. Volatility in global oil and gas prices and how our industry manages the logistical challenges stemming from the COVID-19 pandemic will continue to play a significant role in determining the outlook for the industry, both in the short- and long-term.

Backlog

The following table reflects a summary of our contract drilling backlog coverage of days contracted and related revenue as of December 31, ~~2021~~2022 based on information made available as of that date.

	Percentage of Days Contracted					Revenues Contracted (~~1)(~~in thousands)
	2022	2023	Beyond			2022		2023		Beyond
	2023	2024	Beyond			2023		2024		Beyond
Jackups	49%	0%		0	%	$	23,570	$	—	$	—
Backlog
Drillships	80%	45%		0	%		92,277		47,580		—
Jackups	43%	0%		0	%	$	14,658	$	3,956	$	—
Managed Rigs	25%	0%		0	%		39,358		4,700		—
Drillships	76%	0%		0	%		106,282		20,863		—
Held for Sale	87%	78%		41	%		72,728		57,670		60,366
Third party owned rigs (1)	62%	50%		20	%		65,299		5,881		219

(1)

~~Includes~~The ~~contract~~amounts ~~with~~consist ~~operating~~of ~~dayrates~~(i) ~~that may vary based on~~ a ~~variable~~fixed ~~oil~~management ~~price~~fee ~~index~~paid ~~rate~~to ~~mechanism,~~us ~~which~~pursuant isto ~~calculated utilizing~~ the ~~then-~~applicable ~~average~~management ~~price~~agreement; of(ii) ~~Brent~~a ~~crude. For~~marketing ~~purposes~~fee ofpaid ~~calculating~~to ~~the~~us ~~backlog~~pursuant ~~with~~to ~~contracts~~the ~~that~~applicable ~~contain~~marketing agreement; (iii) a ~~variable~~fixed ~~oil~~management ~~price~~fee ~~indexed~~paid ~~rate~~to ~~mechanism,~~us wepursuant ~~utilize~~to the applicable ~~oil~~EDC ~~price~~Support asServices ofAgreements; ~~quarter-end~~or ~~multiplied~~(iv) bycontract ~~the~~backlog ~~number~~attributable ofto ~~days~~rigs ~~remaining~~owned inby ~~the~~third ~~firm~~parties ~~contract~~where ~~period.~~we ~~The~~enter ~~average~~into ~~dayrate~~contracts ~~over~~directly ~~the~~with ~~term~~customers ofand lease the ~~contract~~rigs ~~could~~through bebareboat ~~lower~~charters orfrom ~~higher depending upon~~ the ~~average~~rig ~~price~~owners. These ofamounts ~~Brent~~exclude ~~crude~~any ~~for~~variable ~~such~~fee ~~measurable~~payable ~~period,~~to ~~and~~us ~~such~~pursuant ~~adjustments~~to ~~are not estimated in~~ the ~~backlog~~applicable ~~dayrate~~management agreement. AsThe ~~certain~~terms of ~~our~~the ~~drilling~~bareboat ~~contracts~~charters are ~~denominated~~consistent inwith ~~currencies other than~~ the ~~USD~~management agreements, ~~backlog~~resulting ~~could~~in ~~also~~the ~~vary~~same ~~due~~financial impact to ~~movements~~us inhad the ~~applicable~~rigs ~~exchange~~remained ~~rates.~~under the management agreements.

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Results of Operations

Operating results for our contract drilling services are dependent on three primary metrics: available days, rig utilization and dayrates. The following table sets forth this selected operational information for the periods indicated:

	Year Ended December 31,
	2021			2020			2019
	2022 (5)			2021 (5)			2020 (5)
Jackups
Rigs available		2			52			5
Available days		730			1,795			1,460
Available days (1)		638			730			1,795
Utilization (1)		68.9	%		56.5	%		97.4	%
Utilization (2)		72.7	%		68.9	%		56.5	%
Average daily revenues (2)	$	106,732		$	60,633		$	63,459
Average daily revenues (3)	$	66,198		$	106,732		$	60,633
Deepwater
Rigs available		2			2			32
Available days		730			1,098			1,095
Available days (1)		730			730			1,098
Utilization (1)		38.4	%		38.9	%		46.1	%
Utilization (2)		94.2	%		38.4	%		38.9	%
Average daily revenues (2)	$	109,043		$	118,129		$	107,660
Average daily revenues (3)	$	155,283		$	109,043		$	118,129
Held for Sale (3)
Sold Rigs/Held for Sale (4)
Rigs available		3			—3			—
Available days		1,095			—			—
Available days (1)		438			1,095			—
Utilization (1)		64.4	%	N/A			N/A
Utilization (2)		43.6	%		64.4	%	N/A
Average daily revenues (2)	$	67,229		N/A			N/A
Average daily revenues (3)	$	73,142		$	67,229		N/A

(1)

Available days are the total number of rig calendar days in the period and excludes rigs under bareboat charter contracts to third parties.

(2)

Utilization is calculated as a percentage of the actual number of revenue earning days divided by the available days in the period. A revenue earning day is defined as a day for which a rig earns dayrate after commencement of operations.

Average daily revenues are based on contract drilling revenues divided by revenue earning days. Average daily revenue will differ from average contract dayrate due to billing adjustments for any non-productive time, mobilization fees and demobilization fees. 45

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(3)

Average daily revenues are based on contract drilling revenues divided by revenue-earning days. Average daily revenue will differ from average contract dayrate due to billing adjustments for any non-productive time, mobilization fees and demobilization fees.

(4)

Each of these rigs were classified as held for sale on our Consolidated Balance Sheets during the Current Year and at December 31, 2021, up to the date of the EDC Closing Date. See “Recent Developments Share Purchase Agreement to Sell EDC to ADES Arabia Holding” in Part I, Item 1 of this Annual Report for additional information.

(5)

Excludes third party owned rigs operated by the Company.

Years Ended December 31, 2022 and 2021

Net loss for the Current Year was $3.4 million, or $0.26 per basic share, on operating revenues of $278.7 million, compared to net loss for the Prior Year of $110.1 million, or $8.40 per basic share, on operating revenues of $158.4 million.

The following table is an analysis of our operating results for the years ended December 31, 2022 and 2021:

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	Year Ended December 31,						Change
	2022			2021			$			%
(in thousands)
Consolidated:
Revenues
Contract drilling services	$	154,116		$	131,703		$	22,413			17	%
Management fees		10,834			2,351			8,483			361	%
Reimbursables and other		113,766			24,366			89,400			367	%
Total revenues		278,716			158,420			120,296			76	%
Operating costs and expenses:
Operating costs		234,832			150,668			84,164			56	%
General and administrative		23,009			20,539			2,470			12	%
Depreciation		44,428			56,242			(11,814	)		-21	%
Gain on EDC Sale		(61,409	)		—			(61,409	)	**
Total operating costs and expenses		240,860			227,449			13,411			6	%
Income (loss) from operations		37,856			(69,029	)		106,885			-155	%
Other (expense) income
Interest income		1,108			124			984			794	%
Interest expense and financing charges		(34,351	)		(34,034	)		(317	)		1	%
Other, net		(3,668	)		(2,171	)		(1,497	)		69	%
Total other expense		(36,911	)		(36,081	)		(830	)		2	%
Income (loss) before income taxes		945			(105,110	)		106,055			-101	%
Income tax provision		4,313			5,141			(828	)		-16	%
Net loss		(3,368	)		(110,251	)		106,883			-97	%
Net loss attributable to noncontrolling interests		(13	)		(114	)		101			-89	%
Net loss attributable to shareholders	$	(3,355	)	$	(110,137	)	$	106,782			-97	%

Drilling Services:
Revenue
Contract drilling services	$	151,509		$	131,703		$	19,806			15	%
Management fees		—			—			—		**
Reimbursables and other		27,685			15,114			12,571			83	%
Total revenue		179,194			146,817			32,377			22	%
Operating costs and expenses:
Operating costs		142,935			140,138			2,797			2	%
General and administrative		—			—			—		**
Depreciation		42,813			54,565			(11,752	)		-22	%
Gain on EDC sale		—			—			—		**
Total operating costs and expenses		185,748			194,703			(8,955	)		-5	%
Loss from operations		(6,554	)		(47,886	)		41,332			-86	%

Managed Services:
Revenue
Contract drilling services	$	2,607		$	—		$	2,607		**
Management fees		10,834			2,351			8,483			361	%
Reimbursables and other		86,081			9,252			76,829			830	%
Total revenue		99,522			11,603			87,919			758	%
Operating costs and expenses:
Operating costs		91,896			10,530			81,366			773	%
General and administrative		—			—			—		**
Depreciation		—			—			—		**
Gain on EDC sale		—			—			—		**
Total operating costs and expenses		91,896			10,530			81,366			773	%
Income from operations		7,626			1,073			6,553			611	%
n/m = not meaningful

Consolidated Revenue: Total revenue increased $120.3 million due primarily to an increase in operating activities in the Current Year as discussed below.

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Drilling Services Revenue: Contract drilling revenue increased $19.8 million for the Current Year as compared to the Prior Year. The increase in contract drilling revenue was primarily the result of the Tungsten Explorer operating during the Current Year compared to the rig being warm stacked during most of the Prior Year and the Platinum Explorer operating 93 more days and at a higher day rate during the Current Year than in the Prior Year. This increase was offset by lower contract drilling revenue for the three jackup rigs included in the EDC Sale (as discussed in “Recent Developments - Share Purchase Agreement to Sell EDC to ADES Arabia Holding” in Part I, Item 1 of this Annual Report) and the Topaz Driller operating fewer days during the Current Year due to routine maintenance. Reimbursables and other revenue increased $12.6 in the Current Year as compared to the Prior Year primarily as a result of the changes in drilling contracts (as discussed immediately above).

Managed Services Revenue: Contract drilling revenue increased $2.6 million in the Current Year due to the Polaris, which began operating under a bareboat charter for the Company. Management fees increased $8.5 million in the Current Year as compared to the Prior Year primarily due to the Capella operating during the Current Year, which we began managing in March 2022 as well as the management of the rigs included in the EDC Sale. The increase in Reimbursables and other revenue for the Current Year as compared to the Prior Year is primarily as a result of the management of the deepwater floaters owned by Aquadrill.

Consolidated Operating Costs: Total operating costs increased 56% due primarily to an increase in operating activities in the Current Year as discussed below.

Drilling Services Operating Costs: Drilling Services Operating costs for the Current Year increased 2% as compared to the Prior Year primarily as a result of changes in activity (as discussed in “Drilling Services Revenue” above). This increase was partially offset by the sale of various assets during the Current Year and the recognition of a net gain of approximately $1.9 million related to the sale of these assets. The Prior Year includes the sale of the Titanium Explorer and the recognition of a net gain of approximately $2.8 million related to the sale of such asset.

Managed Services Operating Costs: The increase in Managed Services operating costs in the Current Year as compared to the Prior Year is the result of our management of certain deepwater floaters (as discussed in “Managed Services Revenue” above).

General and Administrative Expenses: Increases in general and administrative expenses for the Current Year as compared to the Prior Year were primarily due to increased labor costs as the result of the reversal of cost cutting initiatives implemented during 2020 and higher professional fees. General and administrative expenses for the Prior Year included approximately $0.3 million for non-cash share-based compensation expense. Non-cash share-based compensation expense for the Current Year was immaterial.

Depreciation Expense: Depreciation expense is primarily related to rigs owned by us included in our Drilling Services segment. The Managed Services segment does not currently own depreciable assets. Depreciation expense for the Current Year decreased 21% as compared to the Prior Year, due primarily to a decrease in depreciation expense on the three jackup rigs that were classified as held for sale as of December 20, 2021 and subsequently sold in connection with the EDC Sale (which closed on May 27, 2022).

Gain on EDC Sale: During the Current Year, we recorded a net gain of approximately $61.4 million related to the EDC Sale. See “Recent Developments - Share Purchase Agreement to Sell EDC to ADES Arabia Holding” in Part I, Item 1 of this Annual Report for additional details.

Interest Income: Increases in interest income for the Current Year as compared to the Prior Year were due primarily to higher interest rates during the Current Year, which were partially offset by lower cash investments.

Interest Expense and Financing Charges: Interest expense and financing charges includes non-cash deferred financing costs totaling approximately $2.4 million for the Current Year which included a $0.7 million write-off of deferred financing costs as a result of the partial redemption of the 9.25% First Lien Notes as described in “Note 5. Debt” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report, and $1.6 million for the Prior Year.

Other, Net: Our functional currency is USD; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than USD. These transactions are remeasured in USD based on a combination of both current and historical exchange rates. A net foreign currency exchange gain of $3.7 million and $2.2 million were included in Other, net, for the Current Year and the Prior Year, respectively.

Income Tax Provision: Income tax expense decreased in the Current Year as compared to the Prior Year, mainly due to the change in jurisdictions of operations. Our income taxes are generally dependent upon the results of our operations and the local income tax regimes in the jurisdictions in which we operate. In some jurisdictions, we do not pay taxes or receive benefits for certain income and expense items, including interest expense and disposal gains or losses. In other jurisdictions, we are subject to income taxes on a net income basis or a deemed profit basis.

Years Ended December 31, 2021 and 2020

Net loss for the ~~Current~~Prior Year was $110.1 million, or $8.40 per basic share, on operating revenues of $158.4 million, compared to net loss for the ~~Comparable~~Previous Year of $276.7 million, or $21.10 per basic share, on operating ~~revenues~~revenue of $126.9 million.

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The following table is an analysis of our operating results for the years ended December 31, 2021 and 2020:

	Year Ended December 31,						Change
	2021			2020			$			%
(in thousands)
Consolidated:
Revenues
Contract drilling services	$	131,703		$	112,013		$	19,690			18	%
Reimbursables and other		26,717			14,849			11,868			80	%
Management fees		2,351			798			1,553			195	%
Reimbursables and other		24,366			14,051			10,315			73	%
Total revenues		158,420			126,862			31,558			25	%
Operating costs and expenses
Operating costs and expenses:
Operating costs		150,668			149,084			1,584			1	%
General and administrative		20,539			21,022			(483	)		-2	%
Depreciation		56,242			69,216			(12,974	)		-19	%
Loss on impairment		—			128,876			(128,876	)		-100	%
Total operating costs and expenses		227,449			368,198			(140,749	)		-38	%
(Loss) income from operations		(69,029	)		(241,336	)		172,307			-71	%
Loss from operations		(69,029	)		(241,336	)		172,307			-71	%
Other income (expense)
Other (expense) income
Interest income		124			871			(747	)		-86	%
Interest expense and financing charges		(34,034	)		(34,041	)		7			0	%
Other, net		(2,171	)		2,646			(4,817	)		-182	%
Total other expense		(36,081	)		(30,524	)		(5,557	)		18	%
(Loss) income before income taxes		(105,110	)		(271,860	)		166,750			-61	%
Loss before income taxes		(105,110	)		(271,860	)		166,750			-61	%
Income tax provision		5,141			4,897			244			5	%
Net loss		(110,251	)		(276,757	)		166,506			-60	%
Net loss attributable to noncontrolling interests		(114	)		(38	)		(76	)		200	%
Net loss attributable to shareholders	$	(110,137	)	$	(276,719	)	$	166,582			-60	%
Drilling Services:
Revenue
Contract drilling services	$	131,703		$	112,013		$	19,690			18	%
Management fees		—			—			—		**
Reimbursables and other		15,114			13,634			1,480			11	%
Total revenue		146,817			125,647			21,170			17	%
Operating costs and expenses:
Operating costs		140,138			148,444			(8,306	)		-6	%
General and administrative		—			—			—		**
Depreciation		54,565			66,427			(11,862	)		-18	%
Loss on impairment		—			128,876			(128,876	)		-100	%
Total operating costs and expenses		194,703			343,747			(149,044	)		-43	%
Loss from operations		(47,886	)		(218,100	)		170,214			-78	%
Managed Services:
Revenue
Contract drilling services	$	—		$	—		$	—		**
Management fees		2,351			798			1,553			195	%
Reimbursables and other		9,252			417			8,835		n/m
Total revenue		11,603			1,215			10,388			855	%
Operating costs and expenses:
Operating costs		10,530			640			9,890		n/m
General and administrative		—			—			—		**
Depreciation		—			—			—		**
Total operating costs and expenses		10,530			640			9,890		n/m
Income from operations		1,073			575			498			87	%
n/m = not meaningful

Consolidated Revenue: Total revenue increased $31.6 million due primarily to an increase in operating activities in the ~~Current~~Prior Year.

Contract drilling revenue increased $19.7 million for the Current Year as compared to the Comparable Year. The increase in contract drilling revenue was primarily the result of the number of rigs that were operational, with six in the Current Year (including the three jackup rigs classified as held for sale as discussed in "Recent Developments - Share Purchase Agreement to Sell EDC to ADES Arabia Holding and Entry into the ADES Global Strategic Alliance" in this Part I, Item 1) compared to three in the Comparable Year. 49

Reimbursables and other revenue for the Current Year increased 80% as compared to the Comparable Year primarily as a result of the number of our rigs which were operational (as discussed immediately above) and other revenue related to the management of the four deepwater floaters owned by the Aquadrill Entities, which we began managing during the first quarter of 2021 under the terms of the Operating, Management and Marketing Agreements. These increases were offset by decreased reimbursable revenue on the Tungsten Explorer as a result of lower utilization in the Current Year as compared to the Comparable Year.

Operating costs: Operating costs for the Current Year increased 1% as compared to the Comparable Year primarily as a result of the aforementioned changes to our drilling contracts. These increases were offset by (i) decreases on the Platinum Explorer and Tungsten Explorer due to lower utilization in the Current Year compared to the Comparable Year, (ii) the close of the sale of the Titanium Explorer on March 10, 2021, and (iii) the recognition of a net gain of $2.8 million related to the sale of the Titanium Explorer. Operating costs for the Comparable Year includes approximately $5.0 million for bad debt expense associated with our “Trade receivables” and $1.8 million in fuel and helicopter costs that would otherwise be a cost to the customer. These amounts represent our customer’s decision not to pay us for days impacted by what we believe are force majeure and other events for which we would be entitled to receive payment under our contract.

General and administrative expenses: Decreases in general and administrative expenses for the Current Year as compared to the Comparable Year were primarily due to cost cutting initiatives implemented during 2020 to reflect the lower levels of operating activity in the Comparable Year. General and administrative expenses for the Current Year and for the Comparable Year include approximately $0.3 million and $1.1 million, respectively, for non-cash share-based compensation expense.

Depreciation expense: Depreciation expense for the Current Year decreased 19% as compared to the Comparable Year, due primarily to a $11.5 million decrease in depreciation expense on the Titanium Explorer, which was classified as held for sale as of December 31, 2020 and subsequently sold on March 10, 2021.

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~~Loss~~Drilling onServices ~~impairment~~Revenue: ~~During~~Contract drilling revenue increased $19.7 million for the ~~three~~Prior ~~months~~Year ~~ended~~as ~~September~~compared ~~30,~~to ~~2020,~~the wePrevious ~~evaluated~~Year. The ~~our~~increase ~~deepwater~~in contract drilling ~~rigs~~revenue ~~that~~was ~~had~~primarily ~~indicators~~the result of ~~impairment~~the ~~and~~number ~~determined~~of rigs that were operational, with six in the ~~carrying~~Prior ~~value~~Year of(including ~~our~~the ~~longer~~three jackup rigs classified as held for sale as discussed in “Recent Developments -~~term~~ ~~warm~~Share ~~stacked~~Purchase ~~drillship~~Agreement to Sell EDC to ADES Arabia Holding” in this Part I, Item 1 of this Annual Report) compared to three in the ~~Titanium~~Previous ~~Explorer,~~Year. Reimbursables ~~was~~and ~~impaired~~other revenue increased $1.5 Asmillion ain ~~result~~the Prior Year as compared to the Previous Year, weprimarily ~~recognized~~because aof ~~non-cash~~the ~~loss~~number of our rigs which were operational, offset by decreased reimbursable revenue on ~~impairment~~the ofTungsten ~~$128.9~~Explorer ~~million~~as ~~and~~a noresult ~~impact~~of lower utilization in ~~2021~~the Prior Year as compared to the Previous Year.

~~Interest~~Managed ~~income~~Services Revenue: ~~Interest~~Management ~~income~~fees increased $1.6 million for the ~~Current~~Prior Year ~~decreased~~as $0compared to the Previous Year as a result of our management of certain deepwater floaters owned by the Aquadrill Entities, which we began managing during the first quarter of 2021.7 The ~~million~~increase in Reimbursable and other revenue for the Prior Year as compared to the ~~Comparable~~Previous Year ~~due~~is primarily tothe ~~lower~~result ~~interest~~of ~~rates~~our ~~earned~~management onof ~~lower~~the ~~cash~~deepwater ~~investments~~floaters ~~during~~owned ~~the~~by ~~Current~~Aquadrill ~~Year~~(as discussed immediately above).

~~Interest~~Consolidated ~~expense~~Operating ~~and financing charges~~Costs: ~~Interest~~Total ~~expense~~operating ~~and~~costs ~~financing~~increased ~~charges~~1% ~~includes~~due ~~non-cash~~primarily ~~deferred~~to ~~financing~~an ~~costs~~increase ~~totaling~~in ~~approximately~~operating ~~$1.6~~activities ~~million~~in ~~for each of~~ the ~~Current~~(Prior Year ~~and~~as ~~the~~discussed ~~Comparable~~immediately ~~Year~~below).

~~Other,~~Drilling ~~net~~Services Operating Costs: WeDrilling ~~recorded~~Services operating costs for the Prior Year decreased 6% as compared to the Previous Year primarily as a ~~gain~~result of ~~$2.3~~(i) ~~million~~decreases ~~during~~on the ~~Comparable~~Platinum Explorer and Tungsten Explorer due to lower utilization in the Prior Year ~~related~~compared to the ~~settlement~~Previous ~~agreement~~Year, ~~between~~(ii) the ~~Company~~close ~~and~~of ~~its~~the ~~subsidiaries,~~sale onof the ~~one~~Titanium ~~hand~~Explorer on March 10, 2021, and ~~VDC~~(iii) ~~and~~the ~~its~~recognition ~~subsidiaries,~~of ona net gain of $2.8 million related to the ~~other~~sale of the Titanium Explorer. ~~See~~Operating ~~“Note~~costs 8for the Previous Year included approximately $5.0 ~~Commitments~~million ~~and~~for ~~Contingencies”~~bad ofdebt ~~the~~expense ~~“Notes~~associated towith ~~Consolidated~~our ~~Financial~~“Trade ~~Statements~~receivables” inand ~~Part~~$1.8 ~~II,~~million ~~Item~~in 8fuel ofand ~~this~~helicopter ~~Annual~~costs ~~Report~~that ~~for~~would ~~additional~~otherwise ~~detail~~be ona ~~the~~cost ~~settlement~~to ~~agreement~~the customer. ~~The~~These ~~information~~amounts ~~discussed~~represent ~~therein~~our iscustomer’s ~~incorporated~~decision not to pay us for days impacted by ~~reference~~what inwe ~~its~~believe ~~entirety~~are ~~into~~force ~~this~~majeure ~~Part~~and ~~II,~~other ~~Item~~events 7for which we would be entitled to receive payment under our contract.

~~Our~~Managed ~~functional~~Services ~~currency~~Operating isCosts: ~~USD;~~The ~~however,~~increase ain ~~portion~~Managed ofServices ~~the~~operating ~~revenues~~costs ~~earned and expenses incurred by certain of our subsidiaries are denominated~~ in ~~currencies~~the ~~other~~Prior ~~than~~Year ~~USD.~~as ~~These~~compared ~~transactions~~to ~~are~~the ~~remeasured~~Previous inYear ~~USD~~is ~~based~~the onresult ~~a combination~~ of ~~both~~the ~~current~~management ~~and historical exchange rates. A net foreign currency exchange gain~~ of ~~$2.2~~certain ~~million~~deepwater ~~and~~floaters ~~$0.4~~(as ~~million~~discussed ~~were included~~ in ~~other,~~“Managed ~~net,~~Services ~~for~~Revenue” ~~the Current Year and the Comparable Year, respectively~~above.)

~~Income~~General ~~tax~~and ~~provision~~Administrative Expenses: ~~Income~~Decreases ~~tax~~in ~~expense~~general ~~increased~~and inadministrative expenses for the ~~Current~~Prior Year as compared to the ~~Comparable~~Previous Year, ~~mainly~~were primarily due to ~~the~~cost ~~change~~cutting ininitiatives ~~jurisdictions~~implemented ofin ~~operations.~~2020 ~~Our~~to ~~income~~reflect ~~taxes are generally dependent upon~~ the ~~results~~lower levels of ~~our~~operating ~~operations~~activity ~~and the local income tax regimes~~ in the ~~jurisdictions~~Previous ~~in which we operate~~Year. General Inand ~~some~~administrative ~~jurisdictions,~~expenses wefor dothe ~~not~~Prior ~~pay~~Year ~~taxes~~and ~~or receive benefits~~ for ~~certain~~the ~~income~~Previous ~~and~~Year ~~expense~~include ~~items,~~approximately ~~including~~$0.3 ~~interest~~million ~~expense~~ and ~~disposal gains or losses~~$1. In1 ~~other~~million, ~~jurisdictions~~respectively, wefor ~~are~~non-cash ~~subject~~share-based tocompensation ~~income taxes on a net income basis or a deemed profit basis~~expense.

~~Years~~Depreciation ~~Ended~~Expense: Depreciation expense is primarily related to rigs owned by us included in our Drilling Services segment. The Managed Services segment does not currently own depreciable assets. Depreciation expense for the Prior Year decreased 19% as compared to the Previous Year, due primarily to a $11.5 million decrease in depreciation expense on the Titanium Explorer, which was classified as held for sale as of December 31, 2020 and ~~2019~~subsequently sold on March 10, 2021.

~~For~~Loss aon ~~comparison~~Impairment: ofDuring ~~our results of operations for~~ the ~~fiscal~~three ~~years~~months ended ~~December~~September 3130, 2020 ~~and 2019~~, ~~see~~we ~~“Part~~evaluated ~~II,~~our ~~Item~~deepwater 7.drilling ~~Management’s~~rigs ~~Discussion~~that ~~and~~had ~~Analysis~~indicators of ~~Financial~~impairment ~~Condition~~ and ~~Results~~determined ofthat ~~Operations”~~the carrying value of our ~~Annual~~longer-term ~~Report~~warm onstacked ~~Form~~drillship, ~~10-K~~the ~~for~~Titanium ~~the~~Explorer, ~~fiscal~~was ~~year~~impaired. ~~ended~~As ~~December~~a 31result, ~~2020,~~we ~~filed~~recognized ~~with~~a ~~the~~non-cash ~~SEC~~loss on ~~March~~impairment ~~18,~~of $128.9 million and no impact in 2021.

Interest Income: Interest income for the Prior Year decreased $0.7 million as compared to the Previous Year due primarily to lower interest rates earned on lower cash investments during the Prior Year.

Interest Expense and Financing Charges: Interest expense and financing charges includes non-cash deferred financing costs totaling approximately $1.6 million for each of the Prior Year and the Previous Year.

Other, net: We recorded a gain of $2.3 million during the Previous Year related to the settlement agreement between the Company and its subsidiaries, on the one hand, and VDC and its subsidiaries, on the other. See “Note 8. Commitments and Contingencies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report for additional detail on the settlement agreement. The information discussed therein is incorporated by reference in its entirety into this Part II, Item 7.

Our functional currency is USD; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than USD. These transactions are remeasured in USD based on a combination of both current and historical exchange rates. A net foreign currency exchange gain of $2.2 million and $0.4 million were included in other, net, for the Prior Year and the Previous Year, respectively.

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Income tax provision: Income tax expense increased in the Prior Year as compared to the Previous Year, mainly due to the change in jurisdictions of operations. Our income taxes are generally dependent upon the results of our operations and the local income tax regimes in the jurisdictions in which we operate. In some jurisdictions, we do not pay taxes or receive benefits for certain income and expense items, including interest expense and disposal gains or losses. In other jurisdictions, we are subject to income taxes on a net income basis or a deemed profit basis.

Liquidity and Capital Resources

The prolonged low price environment caused by the spread of COVID-19, the resulting decline in global economic activity and the oil price and market share volatility began to reduce our liquidity and capital resources in the second quarter of 2020, a trend which extended throughout 2021 and could extend further into 2022 and beyond, depending on, among other factors, how long COVID-19 remains a significant public health crisis and global economic activity remains challenged. Such events have had significant adverse consequences for general financial, business and economic conditions, as well as for the financial, business and economic position of our business and the business of our customers and suppliers, and may adversely impact our ability to derive cash flows from our operations and access capital funding from third parties in the future.

We experienced, and could experience further delays in the collection of certain accounts receivables due to logistical obstacles, such as office closures resulting from the COVID-19 pandemic, as well as other impacts to our long-term liquidity (see "Ongoing Impact of the COVID-19 Pandemic and Geopolitical Instability Caused by the Conflict in Ukraine" of Part I, Item 1 of this Annual Report for further information pertaining to the ongoing impact of the COVID-19 pandemic, including the spread of its highly transmittable variants and sub-lineages, on our operations and financial condition). Governmental measures, such as widespread lock downs, nightly curfews, territorial entry restrictions and mandates, could impact our ability to operate in locations where such restrictions and requirements are in place, including those locations where we maintain significant operations and derive material revenue. During these uncertain times, we have sought, and continue to seek, measures to reduce our operating costs and preserve cash. We could implement further cost reduction measures (in addition to those previously put in place in 2020 and maintained through the Current Period) and alter our general financial strategy in the near- and long-term.

Sources and Uses of Liquidity

Our anticipated cash flow needs, both in the short- and long-term, ~~may~~will generally include: (i) normal recurring operating expenses; (ii) planned and discretionary capital expenditures; (iii) repayments of interest; and (iv) certain contractual cash obligations and commitments. WeMoreover, we may, from time to time, elect to redeem, repurchase or otherwise acquire ~~our~~ outstanding 9.2550% First Lien Notes through open market purchases, tender offers or pursuant to the terms of such securities. We currently expect to fund our cash flow needs with cash generated by our operations, cash on hand or proceeds from sales of assets.

~~We currently expect to fund our cash flow needs with cash generated by our operations, cash on hand or proceeds from sales of assets.~~ As of December 31, ~~2021~~2022, we believe we maintain adequate cash reserves and are continuously managing our actual cash flow and cash forecasts. Accordingly, ~~our~~ management believes that we have adequate liquidity to fund our operations for the twelve months following the date our Consolidated Financial Statements are issued and therefore, our Consolidated Financial Statements have been prepared under the going concern assumption.

41As of December 31, 2022, we had working capital of approximately $96.2 million, including approximately $74.0 million of cash available for general corporate purposes. Scheduled debt service requirements consist of interest payments of approximately $5.1 million related to the 9.25% First Lien Notes, which were redeemed in full on March 6, 2023 (see “Note 5. Debt” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report for additional information pertaining to the redemption of the 9.25% First Lien Notes) and approximately $9.5 million related to the 9.50% First Lien Notes through December 31, 2023. We anticipate that our capital expenditures through December 31, 2023 will be between approximately $5.9 million and approximately $7.3 million. As our rigs obtain new contracts, we could incur reactivation and mobilization costs for these rigs, as well as customer requested equipment upgrades. These costs could be significant and may not be fully recoverable from the customer. Based on our currently anticipated levels of activity and incremental expenditures through December 31, 2022 for special periodic surveys, major repair and maintenance expenditures and equipment recertifications, our capital expenditures for 2023 are anticipated to be between approximately $14.5 million and approximately $17.7 million.

~~Table~~Concurrently with the issuance of ~~Contents~~the 9.25% First Lien Notes, we entered into a letter of credit agreement with Credit Suisse AG (the “Credit Suisse Letter Agreement”) to replace the letter of credit facility formerly existing under the 2016 Term Loan Facility. The Credit Suisse Letter Agreement provided for up to $50.0 million in letters of credit, with all outstanding letters of credit being cash collateralized. The Credit Suisse Letter Agreement expired in November 2022. We subsequently transitioned our letter of credit needs to JPMorgan Chase Bank N.A., which provides us with individual letters of credit on demand and not part of any formal letter of credit facility. These letters of credit support our bank guarantee and similar needs. As of December 31, 2022, we had letters of credit outstanding in the amount of $21.5 million, $13.6 million of which relate to bank guarantees supporting obligations under drilling contracts we no longer are a party to as they were included in the EDC Sale. In connection with the issuance of the 9.50% First Lien Notes, we are permitted to have up to $25.0 million in letters of credit outstanding to support our operations. As of March 24, 2023 we had letters of credit outstanding in the amount of $11.4 million. This amount includes $3.6 million related to bank guarantees supporting obligations under drilling contracts we no longer are a party to as they were included in the EDC Sale which we expect to be released in 2023.

following the date our Consolidated Financial Statements are issued and therefore, have been prepared under the going concern assumption. To the extent the ADES Sale is not consummated, we believe that cash generated by our operations (including through our $227.9 million of backlog expected to be realized in 2022) together with cash on hand will be sufficient to fund our cash flow needs for the next twelve months. Our 9.25% First Lien Notes mature in November 2023. To the extent additional funds are necessary to meet our long-term liquidity needs as we continue to execute our business strategy, including to satisfy our obligations under the 9.25% First Lien Notes, we anticipate that they will be obtained through incurrence of additional indebtedness, additional equity financings or a combination of these potential sources of funds. There can be no assurance that we will be able to obtain additional funds on terms acceptable to us, on a timely basis or at all. The failure to obtain sufficient funds on acceptable terms when needed could have a material adverse effect on the results of operations, and financial condition.

As of December 31, 2021, we had working capital of approximately $215.8 million, including approximately $73.3 million of cash available for general corporate purposes. Scheduled interest payments through December 31, 2022 are approximately $32.4 million. We do not have any scheduled principal debt maturities until 2023. We anticipate capital expenditures, including upgrades for upcoming contracts, through December 31, 2022 to be between approximately $6.4 million and approximately $7.8 million. As our rigs obtain new contracts, we could incur reactivation and mobilization costs for these rigs, as well as customer requested equipment upgrades. These costs could be significant and may not be fully recoverable from the customer. Based on our currently anticipated levels of activity, incremental expenditures through December 31, 2022 for special periodic surveys, major repair and maintenance expenditures and equipment recertifications to be between approximately $24.0 million and approximately $29.0 million. Approximately $2.5 million and $7.0 million of capital expenditures and incremental expenditures, discussed above, are anticipated to be reimbursed to the Company at the close of the ADES Sale (see "Share Purchase Agreement to Sell EDC to ADES Arabia Holding and Entry into the ADES Global Strategic Alliance" of Part I, Item 1 of this Annual Report for further information). In addition, we expect to receive $170.0 million as purchase price pursuant to the share purchase agreement relating to the ADES Sale. Under the First Lien Indenture, we are required to apply those proceeds to repay, prepay or purchase our senior secured indebtedness (including the 9.25% First Lien Notes), acquire all or substantially all of the assets or capital stock of any other entity engaged in a similar or complementary business to the Company’s lines of business, or make capital expenditures or acquire non-current assets (including vessels and related assets) that are useful in such lines of business (including any deposit or installment payments with respect thereto as well as any expenditures related to the acquisition, construction or “ready for sea” costs of such vessels). To the extent such proceeds are not so applied (or committed to be applied) within one year after receipt, the Company will be required to offer to purchase the 9.25% First Lien Notes with such proceeds. Separately, we will be reimbursed certain expenses not constituting capital expenditures as part of the ADES Sale, capped at $35.0 million. As of December 31, 2021, we had $49.1 million available for the issuance of letters of credit under our cash collateralized letter of credit facility.

The table below includes a summary of our cash flow information for the periods indicated:

		Year Ended December 31,
		2021			2020			2019
		2022			2021			2020
(in thousands)
Cash flows (used in) provided by:
	Operating activities	$	(7018,~~391~~874	)	$	(8570,~~302~~391	)	$	~~535~~(85,~~639~~302	)
	Investing activities		6191,~~512~~523			(36,~~155~~512	)		(73,~~798~~155	)
	Financing activities		—(170,000	)		—			~~(524,284~~—	)

Changes in cash flows from operating activities are driven by changes in net (loss) income (see discussion of changes in net (loss) income above in “Results of Operations” in this Part II, Item 7).

Cash flows provided by investing activities in the Current Year include net proceeds of $198.7 million derived from the EDC Sale and $3.1 million derived from the sale of various assets. The Prior Year includes $13.6 million from the sale of the Titanium Explorer.

~~For~~Cash aflows ~~comparison~~used ofin ~~our~~financing ~~Cash~~activities ~~Flows~~in ~~for~~ the ~~fiscal~~Current ~~years~~Year ~~ended~~include ~~December~~a ~~31,~~partial ~~2020~~redemption ~~and~~of ~~2019,~~the ~~see “Part II, Item 7~~9.25% ~~Management’s~~First ~~Discussion~~Lien ~~and~~Notes ~~Analysis~~as ofdiscussed ~~Financial~~in ~~Condition~~“Note ~~and~~5. ~~Results of Operations~~Debt” of ~~our~~the ~~Annual~~“Notes ~~Report~~to onConsolidated ~~Form~~Financial ~~10-K~~Statements” ~~for~~in ~~the~~Part ~~fiscal year ended December 31~~II, ~~2021,~~Item ~~filed~~8 ~~with~~of ~~the~~this ~~SEC~~Annual ~~on March 18, 2021~~Report.

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For a comparison of our Cash Flows for the fiscal years ended December 31, 2021 and 2020, see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2021, filed with the SEC on March 30, 2022.

The significant elements of the 9.25% First Lien Notes are described in “Note 5. Debt” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report. The information discussed therein is incorporated by reference in its entirety into this Part II, Item 7.

We enter into operating leases in the normal course of business for office space, housing, vehicles and specified operating equipment. Some of these leases contain options that would cause our future cash payments to change if we exercised those options.

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Contractual Obligations

A description of our material contractual obligations as of December 31, ~~2021~~2022 is set forth immediately below. Some of the figures discussed therein are based on our estimates and assumptions about these obligations, including their duration and other factors. The contractual obligations we may actually pay in future periods may vary from those reflected in the table because the estimates and assumptions are subjective.

•

Principal payments on the 9.25% First Lien Notes as discussed in “Note 5. Debt” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report (the information discussed therein is incorporated by reference in its entirety into this Part II, Item 7).

•

Interest on the 9.25% First Lien Notes iswas payable at 9.25% in May and November ofor each year until the maturity date of the 9.25% First Lien Notes on November 15, 2023. See additional information regarding scheduled payments through December 31, ~~2022~~2023 above in “Liquidity and Capital Resources” in this Part II, Item 7, which is incorporated by reference in its entirety into this Part II, Item 7).

•

Operating lease payments as discussed in “Note 4. Leases” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report (the information discussed therein is incorporated by reference in its entirety into this Part II, Item 7).

•

Our purchase obligations as discussed in “Note 8. Commitments and Contingencies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report (the information discussed therein is incorporated by reference in its entirety into this Part II, Item 7).

Commitments and Contingencies

We are subject to litigation, claims and disputes in the ordinary course of business, some of which may not be covered by insurance. Information regarding our legal proceedings is set forth in “Note 8. Commitments and Contingencies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report. The information discussed therein is incorporated by reference in its entirety into this Part II, Item 7.

There is an inherent risk in any litigation or dispute and no assurance can be given as to the outcome of any claims. We do not believe the ultimate resolution of any existing litigation, claims or disputes will have a material adverse effect on our financial position, results of operations or cash flows.

Critical Accounting Estimates

The preparation of financial statements and related disclosures in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Our significant accounting policies are included in “Note 2. Basis of Presentation and Significant Accounting Policies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report. While management believes current estimates are appropriate and reasonable, actual results could materially differ from those estimates. We have identified the policies below as critical to our business operations and the understanding of our financial operations. We have discussed the development, selection and disclosure of such policies and estimates with the audit committee of the Board of Directors.

Property and Equipment: Our long-lived assets, primarily consisting of the values of our drilling rigs included in the Drilling Services segment, are the most significant amount of our total assets. WeMaintenance ~~make~~and ~~judgments~~routine ~~with~~repairs ~~regard~~are charged to ~~the~~income ~~carrying~~while ~~value~~replacements ofand ~~these~~betterments ~~assets,~~that ~~including~~upgrade ~~amounts~~or ~~capitalized,~~increase ~~componentization,~~the ~~depreciation~~functionality ~~and~~of ~~amortization~~our ~~methods,~~existing ~~salvage~~equipment ~~values~~ and ~~estimated~~that significantly extend the useful ~~lives.~~life ~~Drilling~~of ~~rigs~~an existing asset are ~~depreciated~~capitalized. onSignificant ajudgments, ~~component~~assumptions ~~basis~~and ~~over~~estimates ~~estimated~~may ~~useful~~be ~~lives~~required onin adetermining ~~straight-line~~whether ~~basis~~or asnot ofsuch replacements and betterments meet the ~~date~~criteria ~~placed~~for capitalization and in ~~service.~~determining ~~Other~~useful ~~assets~~lives ~~are~~and ~~depreciated~~salvage ~~upon~~values ~~placement~~of such assets. Changes in ~~service~~these ~~over~~judgments, ~~estimated~~assumptions ~~useful~~and ~~lives~~estimates oncould aproduce ~~straight-line~~results ~~basis~~that differ from those reported.

We evaluate the realization of property and equipment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. An impairment loss on our property and equipment exists when estimated undiscounted cash flows expected to result from the use of the asset and its eventual disposition are less than its carrying amount. Any impairment loss recognized would be computed as the excess of the asset’s carrying value over the estimated fair value. Estimates of future cash flows require us to make long-term forecasts of our future revenues and operating costs with regard to the assets subject to review. Our business, including the utilization rates and dayrates we receive for our drilling rigs, depends on the level of our customers’ expenditures for oil and gas exploration, development and production expenditures. Oil and gas prices and customers’ expectations of potential changes in these prices, the general outlook for worldwide economic growth, political and social stability in the major oil and gas producing basins of the world, availability of credit and changes in governmental laws and regulations, among many other factors, significantly affect our customers’ levels of expenditures. Sustained declines in or persistent depressed levels of oil and gas prices, worldwide rig counts and utilization, reduced access to credit markets, reduced or depressed sale prices of comparably equipped jackups 52

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We evaluate the realization of property and ~~drillships~~equipment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. An impairment loss on our property and ~~any~~equipment ~~other~~exists ~~significant~~when ~~adverse~~estimated ~~economic~~undiscounted ~~news~~cash ~~could~~flows expected to result from the use of the asset and its eventual disposition are less than its carrying amount. Any impairment loss recognized would be computed as the excess of the asset’s carrying value over the estimated fair value. Estimates of future cash flows require us to ~~evaluate~~make ~~the~~long-term ~~realization~~forecasts of our ~~drilling~~future ~~rigs.~~revenues ~~During~~and operating costs with regard to the ~~third~~assets ~~quarter~~subject ofto ~~2020~~review. Our business, including the utilization rates and dayrates we ~~identified~~receive ~~indicators~~for ~~that~~our ~~the~~drilling ~~carrying~~rigs, ~~amounts~~depends on the level of our ~~deepwater~~customers’ ~~asset~~expenditures ~~groups~~for ~~may~~oil ~~not~~and begas ~~recoverable~~exploration, development and production expenditures. ~~Such~~Oil ~~indicators~~and ~~included~~gas ~~the~~prices ~~continued~~and ~~impact~~customers’ expectations of ~~COVID-19~~potential onchanges ~~global~~in these prices, the general outlook for worldwide economic ~~activity~~growth, political and social stability in the ~~resulting~~major ~~reductions~~oil and ~~delays~~gas producing basins of the world, availability of credit and changes in ~~deepwater~~governmental laws and regulations, among many other factors, significantly affect our customers’ levels of expenditures. Sustained declines in or persistent depressed levels of oil and gas ~~exploration~~prices, worldwide rig counts and ~~development~~utilization, ~~plans~~reduced onaccess ~~the~~to ~~part~~credit markets, reduced or depressed sale prices of ~~operators~~comparably ~~leading~~equipped tojackups ~~increased~~and ~~barriers~~drillships ~~for~~and any other significant adverse economic news could require us to evaluate the ~~reactivation~~realization of ~~stacked~~our drilling rigs. AsManagement’s aassumptions ~~result~~are necessarily subjective and are an inherent part of our asset impairment ~~testing~~evaluation, weand ~~determined~~the ~~that~~use ~~the~~of ~~carrying~~different ~~amount~~assumptions ofcould ~~our~~produce ~~long-term~~results ~~warm~~that ~~stacked~~differ ~~drillship,~~from ~~the~~those ~~Titanium~~reported. ~~Explorer,~~Our ~~was~~methodology ~~impaired~~generally ~~and~~involves wethe ~~recognized~~use aof ~~non-cash~~significant ~~loss~~unobservable oninputs, ~~impairment~~representative of ~~$128.9~~a ~~million~~Level as3 offair ~~September~~value ~~30, 2020~~measurement.

AsDuring athe ~~result~~third quarter of 2020, we identified indicators that the ~~ADES~~carrying ~~Purchase~~amounts ~~Agreement~~of ~~(as~~our ~~defined~~deepwater ~~above~~asset ingroups ~~Part~~may I,not ~~Item~~be 1recoverable. ~~Business~~Such ~~under~~indicators ~~"Recent~~included ~~Developments~~the -continued ~~Share~~impact ~~Purchase~~of ~~Agreement~~COVID-19 toon ~~Sell~~global ~~EDC~~economic toactivity ~~ADES~~and ~~Arabia~~the ~~Holding~~resulting reductions and ~~Entry~~delays ~~into~~in ~~the~~deepwater ~~ADES~~oil ~~Global~~and ~~Strategic~~gas ~~Alliance"),~~exploration weand ~~tested~~development plans on the ~~rigs~~part of operators leading to beincreased ~~included~~barriers infor the ~~EDC~~reactivation ~~entity~~of ~~for~~stacked ~~impairment~~rigs. ~~The~~As ~~recoverability~~a ~~test~~result ~~performed~~of ~~resulted~~our inimpairment notesting, ~~impairment~~we ~~loss~~determined ~~being~~that ~~recorded~~the ascarrying amount of our long-term warm stacked drillship, the ~~estimated~~Titanium ~~undiscounted~~Explorer, ~~cash~~was ~~flows~~impaired ~~generated~~and ~~from~~we ~~these~~recognized ~~drilling~~a ~~rigs~~non-cash ~~exceed~~loss ~~the~~on ~~carrying~~impairment ~~values~~of $128.9 million as of September 30, 2020. The Company performed a recoverability analysis for the years ended December 31, 2022 and 2021, and no impairment loss was recorded.

Income Taxes: VDI is a Cayman Islands company. The Cayman Islands do not impose corporate income taxes. Consequently, we have calculated income taxes based on the laws and tax rates in effect in the countries in which our operations are conducted, or in which we and our subsidiaries are considered resident for income tax purposes. We operate in multiple countries under different legal forms. As a result, we are subject to the jurisdiction of numerous domestic and foreign tax authorities, as well as to tax agreements and treaties among these governments. Tax rates vary between jurisdictions, as does the tax base to which the rates are applied. Taxes may be levied based on net profit before taxes or gross revenues or as withholding taxes on revenue. Determination of income tax expense in any jurisdiction requires the interpretation of the related tax laws and regulations and the use of estimates and assumptions regarding significant future events, such as the amount, timing and character of deductions, permissible revenue recognition methods under the tax law and the sources and character of income and tax credits. We recognize interest and penalties related to income taxes as a component of income tax expense.

Our income tax expense may vary substantially from one period to another as a result of changes in the tax laws, regulations, agreements and treaties, foreign currency exchange restrictions and fluctuations, rig movements or our level of operations or profitability in each tax jurisdiction. Furthermore, our income taxes are generally dependent upon the results of our operations and when we generate significant revenues in jurisdictions where the income tax liability is based on gross revenues or asset values, there is no correlation to the net operating results and the income tax expense.

Furthermore, in some jurisdictions we do not pay taxes or pay taxes at low rates or receive benefits for certain income and expense items, including interest expense, loss on extinguishment of debt, gains or losses on disposal or transfer of assets, reorganization expenses and write-off of development costs. In certain jurisdictions we are taxed under preferential tax regimes, which may require our compliance with specified requirements to sustain the tax benefits. We believe we are in compliance with the specified requirements and will continue to make all reasonable efforts to comply; however, our ability to meet the requirements of the preferential tax regimes may be affected by changes in laws or administrative practices, our business operations and other factors affecting the Company and industry, many of which are beyond our control.

We do not establish deferred tax liabilities for certain of our foreign earnings that we intend to indefinitely reinvest to finance foreign activities. Should a future distribution be made from any unremitted earnings of our foreign subsidiaries, we may be required to record additional taxes in certain jurisdictions. However, it is not practical at this time to estimate the unremitted earnings or the potential tax liability due to the complexity of the hypothetical calculations.

Deferred income tax assets and liabilities are recorded for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. We provide for deferred taxes on temporary differences between the financial statements and tax bases of assets and liabilities using the enacted tax rates which are expected to apply to taxable income when the temporary differences are expected to reverse. Deferred tax assets are also provided for certain tax losses and tax credit carryforwards. ~~A valuation allowance is established to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax asset will not be realized.~~

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A valuation allowance is established to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax asset will not be realized.

Recent Accounting Standards: See “Note 2. Basis of Presentation and Significant Accounting Policies” of the “Notes to Consolidated Financial Statements” in Part II, Item 8 of this Annual Report for further information. The information discussed therein is incorporated by reference in its entirety into this Part II, Item 7.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

Our rigs operate in various international locations and thus are sometimes subject to foreign exchange risk. We may from time to time also be exposed to certain commodity price risk, equity price risk and risks related to other market driven rates or prices. We do not enter into derivatives or other financial instruments for trading or speculative purposes. The significant decline in worldwide exploration and production spending as a result of reduced oil prices since 2014 has negatively impacted the offshore contract drilling business as discussed in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Interest Rate Risk: As of December 31, ~~2021~~2022, we had no variable rate debt outstanding.

44Foreign Currency Exchange Rate Risk. Our functional currency is USD, which is consistent with the oil and gas industry. However, outside the United States, a portion of our expenses are incurred in local currencies. Therefore, when USD weakens (strengthens) in relation to the currencies of the countries in which we operate, our expenses reported in USD will increase (decrease). A substantial majority of our revenues are received in USD, our functional currency; however, in certain countries in which we operate, local laws or contracts may require us to receive some payment in the local currency. We are exposed to foreign currency exchange risk to the extent the amount of our monetary assets denominated in the foreign currency differs from our obligations in that foreign currency. In order to mitigate the effect of exchange rate risk, we attempt to limit foreign currency holdings to the extent they are needed to pay liabilities in the local currency. To further manage our exposure to fluctuations in currency exchange rates, foreign exchange derivative instruments, specifically foreign exchange forward contracts, or spot purchases, may be used. A foreign exchange forward contract obligates us to exchange predetermined amounts of specified foreign currencies at specified exchange rates on specified dates or to make an equivalent USD payment equal to the value of such exchange. We do not enter into derivative transactions for speculative purposes. As of December 31, 2022, we did not have any open foreign exchange derivative contracts or material foreign currency exposure risk.

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Foreign Currency Exchange Rate Risk. Our functional currency is USD, which is consistent with the oil and gas industry. However, outside the United States, a portion of our expenses are incurred in local currencies. Therefore, when USD weakens (strengthens) in relation to the currencies of the countries in which we operate, our expenses reported in USD will increase (decrease). A substantial majority of our revenues are received in USD, our functional currency; however, in certain countries in which we operate, local laws or contracts may require us to receive some payment in the local currency. We are exposed to foreign currency exchange risk to the extent the amount of our monetary assets denominated in the foreign currency differs from our obligations in that foreign currency. In order to mitigate the effect of exchange rate risk, we attempt to limit foreign currency holdings to the extent they are needed to pay liabilities in the local currency. To further manage our exposure to fluctuations in currency exchange rates, foreign exchange derivative instruments, specifically foreign exchange forward contracts, or spot purchases, may be used. A foreign exchange forward contract obligates us to exchange predetermined amounts of specified foreign currencies at specified exchange rates on specified dates or to make an equivalent USD payment equal to the value of such exchange. We do not enter into derivative transactions for speculative purposes. As of December 31, 2021, we did not have any open foreign exchange derivative contracts or material foreign currency exposure risk.

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Item 8. Financial Statements and Supplementary Data.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and Board of Directors of

Vantage Drilling International

Houston, Texas

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Vantage Drilling International (the “Company”) as of December 31, ~~2021~~2022 and ~~2020~~2021, the related consolidated statements of operations, shareholders’ equity, and cash flows for each of the three years in the period ended December 31, ~~2021~~2022, 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~~2022 and ~~2020~~2021, and the results of its operations and its cash flows for each of the three years in the period ended December 31, ~~2021~~2022, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“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 consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated 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 consolidated 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 consolidated 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 consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of 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~~opinions on the critical audit matter or on the accounts or disclosures to which it relates.

Property and Equipment Impairment Assessment

AsThe ~~described in Note 9 of the~~ Company's ~~consolidated financial statements, the net carrying value of property and equipment classified as held for sale as of December 31, 2021 was $87.4 million. As described in Note 2, the Company~~ evaluates the recoverability of property and equipment whenever events or changes in circumstances indicate that ~~the~~their carrying ~~amount~~values ~~of an asset group~~ may not be recoverable ("triggering events"). ~~During~~As ~~2021,~~a ~~the~~result ~~Company~~of ~~entered~~a ~~into~~triggering ~~the~~event ~~ADES~~identified ~~Purchase~~during ~~Agreement to sell all of~~ the ~~issued~~quarter ~~and~~ended ~~outstanding~~December ~~equity~~31, ~~of Emerald Driller Company~~2022, ~~which owns~~ the ~~Emerald~~Company ~~Driller,~~reviewed ~~the~~certain ~~Sapphire~~of ~~Driller~~its property and ~~the~~equipment ~~Aquamarine~~for ~~Driller jackup rigs~~recoverability. ~~The~~An ~~Company~~impairment ~~determined~~is ~~this~~recorded ~~event~~when ~~constituted~~the aestimated ~~triggering~~undiscounted ~~event~~cash ~~requiring~~flows anexpected ~~assessment~~to ofresult ~~whether~~from ~~each~~the ~~asset~~use ~~group~~of ~~was~~the ~~recoverable~~property and ~~determined~~equipment ~~that~~and ~~the~~its ~~carrying~~eventual ~~value~~disposition ofare ~~each~~less ~~asset~~than ~~group~~its ~~was~~carrying ~~recoverable as of December 31, 2021~~amount.

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We identified the ~~significant~~determination ~~judgments~~of ~~made by management to prepare~~ the undiscounted future cash ~~flow~~flows ~~analyses~~of bycertain ~~asset~~of ~~group~~the toCompany’s ~~evaluate~~property ~~whether~~and anequipment ~~impairment~~used ~~existed~~in ~~for~~the ~~each~~impairment ~~asset~~assessment ~~group~~to asbe a critical audit matter. ~~Significant~~The ~~assumptions~~principal ~~used~~considerations infor our determination were certain of the judgments and estimates made by the Company to prepare the undiscounted cash flows, ~~estimates~~specifically ~~included~~ the ~~effect~~effects of ~~day~~dayrates ~~rates~~ and utilization metrics. Auditing these elements was ~~especially~~ challenging and required significant auditor judgment due to the nature and extent of audit effort required in performing procedures and evaluating audit evidence related to management’s assumptions.

The primary procedures we performed to address this critical audit matter included:

•

Evaluating the reasonableness of certain of the ~~dayrate~~dayrates and utilization metrics assumptions used in the undiscounted cash flow estimates by (i) testing the completeness and accuracy of current backlog and (ii) considering available industry reports and data on supply and demand trends, ~~and~~as well as future oil and gas prices.

•

Comparing the dayrates and utilization metrics assumptions used in the Company’s ~~historic~~ undiscounted cash flow estimates to historical results to assess for management biases in the estimates.

~~(Signed~~/s/ BDO USA, LLP)

We have served as the Company's auditor since 2014.

Houston, Texas

March 30, ~~2022~~2023

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Vantage Drilling International

Consolidated Balance Sheets

(In thousands, except share data)

	December 31, 2021			December 31, 2020
	December 31, 2022			December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	7374,~~343~~026		$	~~141~~73,~~945~~343
Restricted cash		116,~~621~~450			71,~~996~~621
Trade receivables, net of allowance for doubtful accounts of $5.0 million each year		37,527			24,717
Trade receivables, net of allowance for credit losses of $5.0 million each year		62,776			37,527
Materials and supplies		3741,~~580~~250			4937,~~861~~580
Assets held for sale		~~117,117~~—			10117,~~113~~117
Prepaid expenses and other current assets		1825,~~309~~621			1918,~~038~~309
Total current assets		~~285~~220,~~497~~123			~~253~~285,~~670~~497
Property and equipment
Property and equipment		~~645~~647,~~622~~909			~~794~~645,~~944~~622
Accumulated depreciation		(~~266~~309,~~018~~453	)		(~~278~~266,~~562~~018	)
Property and equipment, net		~~379~~338,~~604~~456			~~516~~379,~~382~~604
Operating lease ROU assets		21,~~450~~648			32,~~997~~450
Other assets		3118,~~843~~334			1231,~~126~~843
Total assets	$	~~699~~578,~~394~~561		$	~~786~~699,~~175~~394
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Accounts payable	$	3157,~~420~~775		$	2531,~~466~~420
Other current liabilities		3166,~~533~~179			2431,~~734~~533
Liabilities held for sale		~~6,720~~—			—6,720
Total current liabilities		69123,~~673~~954			5069,~~200~~673
Long–term debt, net of discount and financing costs of $3,142 and $4,781		346,858			345,219
Long–term debt, net of discount and financing costs of $773 and $3,142		179,227			346,858
Other long-term liabilities		1712,~~012~~881			1517,~~011~~012
Commitments and contingencies (see Note 8)
Shareholders' equity
Ordinary shares, $0.001 par value, 50 million shares authorized; 13,115,026 shares issued and outstanding each year		13			13
Additional paid-in capital		633,~~847~~863			~~634~~633,~~181~~847
Accumulated deficit		(~~369~~373,~~792~~147	)		(~~259~~369,~~655~~792	)
Controlling interest shareholders' equity		~~264~~260,~~068~~729			~~374~~264,~~539~~068
Noncontrolling interests		1,~~783~~770			1,~~206~~783
Total equity		~~265~~262,~~851~~499			~~375~~265,~~745~~851
Total liabilities and shareholders’ equity	$	~~699~~578,~~394~~561		$	~~786~~699,~~175~~394

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

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Consolidated Statement of Operations

(In thousands, except per share data)

	Year Ended December 31,
	2021			2020			2019
	2022			2021			2020
Revenue
Contract drilling services	$	~~131~~154,~~703~~116		$	~~112~~131,~~013~~703		$	~~144~~112,~~571~~013
Contract termination revenue		—			—			594,029
Management fees		10,834			2,351			798
Reimbursables and other		26113,~~717~~766			1424,~~849~~366			2214,~~248~~051
Total revenue		~~158~~278,~~420~~716			~~126~~158,~~862~~420			~~760~~126,~~848~~862
Operating costs and expenses
Operating costs		~~150~~234,~~668~~832			~~149~~150,~~084~~668			~~156~~149,~~893~~084
General and administrative		2023,~~539~~009			2120,~~022~~539			~~128~~21,~~548~~022
Depreciation		5644,~~242~~428			6956,~~216~~242			7369,~~820~~216
Loss on impairment		—			128,876			—
Gain on EDC Sale		(61,409	)		—			—
Total operating costs and expenses		227,449			368,198			359,261
Loss on impairment		—			—			128,876
(Loss) income from operations		(69,029	)		(241,336	)		401,587
Total operating costs and expenses		240,860			227,449			368,198
Income (loss) from operations		37,856			(69,029	)		(241,336	)
Other income (expense)
Interest income		~~124~~1,108			~~871~~124			~~116,368~~871
Interest expense and other financing charges		(34,~~034~~351	)		(34,~~041~~034	)		(4634,~~575~~041	)
Other, net		(23,~~171~~668	)		(2,~~646~~171	)		~~216~~2,646
Total other (expense) income		(36,081	)		(30,524	)		70,009
Total other expense		(36,911	)		(36,081	)		(30,524	)
(Loss) income before income taxes		(105,110	)		(271,860	)		471,596
Income (loss) before income taxes		945			(105,110	)		(271,860	)
Income tax provision		54,~~141~~313			45,~~897~~141			154,~~121~~897
Net (loss) income		(110,251	)		(276,757	)		456,475
Net loss		(3,368	)		(110,251	)		(276,757	)
Net (loss) income attributable to noncontrolling interests		(114	)		(38	)		741
Net loss attributable to noncontrolling interests		(13	)		(114	)		(38	)
Net (loss) income attributable to shareholders	$	(110,137	)	$	(276,719	)	$	455,734
Net loss attributable to shareholders	$	(3,355	)	$	(110,137	)	$	(276,719	)
(Loss) earnings per share
Loss per share
Basic and Diluted	$	(80.4026	)	$	(218.1040	)	$	(2821.2910	)

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

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Consolidated Statement of Shareholders' Equity

(In thousands)

	Ordinary Shares
	Shares		Amount		Additional Paid-in Capital			Accumulated Earnings (Deficit)			Non-Controlling Interests			Total Equity (Deficit)
Balances as of December 31, 2018		5,000	$	5	$	373,972		$	(438,670	)	$	—		$	(64,693	)
Common stock issued (see Note 6)		8,115		8		779,071			—			—			779,079
Reclassification of Share-based compensation (see Note 6)		—		—		12,087			—			—			12,087
Distribution to shareholders (see Note 6)		—		—		(524,994	)		—			—			(524,994	)
Share-based compensation		—		—		435			—			—			435
Share-based compensation - dividend equivalents (see Note 6)		—		—		(5,801	)		—			—			(5,801	)
Contributions from holders of noncontrolling interests		—		—		—			—			503			503
Net income		—		—		—			455,734			741			456,475
Balances as of December 31, 2019		13,115	$	13	$	634,770		$	17,064		$	1,244		$	653,091
Share-based compensation		—		—		1,615			—			—			1,615
Share-based compensation - dividend equivalents (see Note 6)		—		—		(2,204	)		—			—			(2,204	)
Net loss		—		—		—			(276,719	)		(38	)		(276,757	)
Balances as of December 31, 2020		13,115	$	13	$	634,181		$	(259,655	)	$	1,206		$	375,745
Share-based compensation		—		—		395			—			—			395
Share-based compensation - dividend equivalents (see Note 6)		—		—		(729	)		—			—			(729	)
Contributions from holders of noncontrolling interests (see Note 9)		—		—		—			—			691			691
Net loss		—		—		—			(110,137	)		(114	)		(110,251	)
Balances as of December 31, 2021		13,115	$	13	$	633,847		$	(369,792	)	$	1,783		$	265,851
Share-based compensation		—		—		79			—			—			79
Share-based compensation - dividend equivalents (see Note 6)		—		—		(63	)		—			—			(63	)
Net loss		—		—		—			(3,355	)		(13	)		(3,368	)
Balances as of December 31, 2022		13,115	$	13	$	633,863		$	(373,147	)	$	1,770		$	262,499

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

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Consolidated Statement of Cash Flows

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

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