What changed in this filing

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Item 1. Business

2022-02-22 compared with 2021-03-02 · 131 added, 220 removed, 168 unchanged (68% of the section changed)

Valaris plc is a global offshore contract drilling company.

Unless the context requires otherwise, the terms "Valaris," "Company," "we," "us" and "our" refer to Valaris plc together with all its subsidiaries and predecessors.

Valaris Limited is a global offshore contract drilling company.

Unless the context requires otherwise, the terms "Valaris," "Company," "we," "us" and "our" refer to Valaris Limited together with all its subsidiaries and predecessors.

We are a leading provider of offshore contract drilling services to the international oil and gas industry.

We currently own an offshore drilling rig fleet of 61 rigs, with drilling operations in almost every major offshore market across five continents.

We currently own an offshore drilling rig fleet of 56 rigs, with drilling operations in almost every major offshore market across six continents.

Our rig fleet includes 11 drillships, four dynamically positioned semisubmersible rigs, one moored semisubmersible rig, 40 jackup rigs and a 50% equity interest in Saudi Aramco Rowan Offshore Drilling Company ("ARO"), our 50/50 joint venture with Saudi Aramco, which owns an additional seven rigs.

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Our customers include many of the leading national and international oil companies, in addition to many independent operators.

We are among the most geographically diverse offshore drilling companies, with current operations spanning nine countries on five continents.

We are among the most geographically diverse offshore drilling companies, with current operations spanning 14 countries.

The markets in which we operate include the Gulf of Mexico, the North Sea, the Middle East, West Africa, Australia and Southeast Asia.

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Our customers bear substantially all of the costs of constructing the well and supporting drilling operations, as well as the economic risk relative to the success of the well.

Following several years of market volatility beginning with oil price declines in 2014, as we entered 2020, we expected that volatility to continue over the near-term with the expectation that long-term oil prices would remain at levels sufficient to support a continued gradual recovery in the demand for offshore drilling services.

As we entered 2020, we expected the volatility that began with the oil price decline in 2014 to continue over the near-term with the expectation that long-term oil prices would remain at levels sufficient to support a continued gradual recovery in the demand for offshore drilling services.

We were focused on opportunities to put our rigs to work, manage liquidity, extend our financial runway, and reduce debt as we sought to navigate the extended market downturn and improve our balance sheet.

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As a consequence, the price of Brent crude oil fell from around $60 per barrel at year-end 2019 to around $20 per barrel in mid-April 2020.

In response to dramatically reduced oil price expectations for the near term, our customers reviewed, and in most cases lowered significantly, their capital expenditure plans in light of revised pricing expectations.

This caused our customers to cancel or shorten the duration of many of our 2020 drilling contracts, cancel future drilling programs and seek pricing and other contract concessions which led to material operating losses and liquidity constraints for us.

While there has been some recent improvement to Brent crude oil prices, to approximately $65 per barrel in February 2021, there is still a significant amount of uncertainty around the sustainability of the improvement in oil prices to support a recovery in demand for offshore drilling services.

Additionally, the full impact that the pandemic and the decline in oil prices will have on our results of operations, financial condition, liquidity and cash flows is uncertain due to numerous factors, including the duration and severity of the outbreak, the effectiveness of the ongoing vaccine rollout, the duration of the oil price and

demand decline, and the extent of disruptions to our operations.

To date, the COVID-19 pandemic has resulted in only limited operational downtime.

In response to dramatically reduced oil price expectations, our customers reviewed, and in most cases lowered significantly, their capital expenditure plans in light of revised pricing expectations.

This caused our customers, primarily in the second and third quarters of 2020, to cancel or shorten the duration of many of our drilling contracts, cancel future drilling programs and seek pricing and other contract concessions which led to material operating losses and liquidity constraints for us.

In 2020, the combined effects of the global COVID-19 pandemic, the significant decline in the demand for oil and the substantial surplus in the supply of oil resulted in significantly reduced demand and day rates for offshore drilling provided by the Company and increased uncertainty regarding long-term market conditions.

These events had a significant adverse impact on our current and expected liquidity position and financial runway and led to the filing of the Chapter 11 Cases (as defined herein).

In 2021, Brent crude oil prices increased from approximately $50 per barrel at the beginning of 2021 to nearly $80 per barrel by the end of the year and have subsequently increased to over $90 per barrel in early 2022.

Increased oil prices are due to, among other factors, rebounding demand for hydrocarbons, a measured approach to production increases by OPEC+ members and a focus on cash flow and returns by major exploration and production companies.

The constructive oil price environment led to an improvement in contracting and tendering activity in 2021 as compared to 2020.

Benign floater rig years awarded in 2021 were more than double the amount awarded in 2020.

This increase in activity is particularly evident for drillships with several multi-year contracts awarded and a meaningful improvement in day rates for this class of assets.

Jackup contracting activity also increased in 2021, but at a more modest pace than for floaters;

however, demand for jackups did not decline as significantly in 2020 as it did for floaters.

While the near-term outlook for the offshore drilling industry has improved, particularly for floaters, since the beginning of 2021, the global recovery from the COVID-19 pandemic remains uneven, and there is still uncertainty around the sustainability of the improvement in oil prices and the recovery in demand for offshore drilling services.

Additionally, the full impact that the pandemic and the volatility of oil prices will have on our results of operations, financial condition, liquidity and cash flows is uncertain due to numerous factors, including the duration and severity of the pandemic, the continued effectiveness of the ongoing vaccine rollout, the general resumption of global economic activity along with the injection of substantial government monetary and fiscal stimulus and the sustainability of the improvements in oil prices and demand in the face of market volatility.

To date, the COVID-19 pandemic has resulted in limited operational downtime.

Our rigs have had to shut down operations while crews are tested and incremental sanitation protocols are implemented and while crew changes have been restricted as replacement crews are quarantined.

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There can be no assurance that these, or other issues caused by the COVID-19 pandemic, will not materially affect our ability to operate our rigs in the future.

We expect that these challenges will continue for drilling contractors as customers wait to gain additional clarity on commodity pricing and seek to reduce costs in the near-term by attempting to renegotiate existing contract terms.

We believe the current market and macro-economic conditions will create a challenging contracting environment through 2021 and into 2022 and potentially beyond.

The combined effects of the global COVID-19 pandemic, the significant decline in the demand for oil and the substantial surplus in the supply of oil have resulted in significantly reduced demand and day rates for offshore drilling provided by the Company and increased uncertainty regarding long-term market conditions.

These recent events have had a significant adverse impact on our current and expected liquidity position and financial runway and led to the filing of the Chapter 11 Cases (as defined herein).

While we have and are continuing to pursue a variety of cost-cutting measures such as further reductions in corporate overhead and discretionary expenditures, reductions in capital expenditures and an increased focus on operational efficiencies, we determined that based on our significant level of indebtedness and the circumstances described above that a comprehensive restructuring of our indebtedness was needed to improve our financial position.

As more fully described in “ Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” to our consolidated financial statements included in "Item 8.

Financial Statements and Supplementary Data", the Company will undergo a financial restructuring that is intended to reduce debt levels substantially, support continued operations during the current lower demand environment and provide a robust financial platform to take advantage of market recovery over the long-term.

Chapter 11 Proceedings and Ability to Continue as a Going Concern

On August 19, 2020 (the “Petition Date”), Valaris plc and certain of its direct and indirect subsidiaries (collectively, “the Debtors") filed voluntary petitions for reorganization under chapter 11 of the United States Bankruptcy Code (“Bankruptcy Code”) in the Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”).

As part of the chapter 11 cases under the caption In re Valaris plc, et al., Case No.

20-34114 (MI) (the “Chapter 11 Cases”), the Debtors were granted “first-day” relief which enabled the Company to continue operating without interruption or disruption to its relationships with its customers and vendors or its high-quality service delivery.

In particular, employee pay and benefits are expected to continue without interruption.

On August 18, 2020, the Debtors entered into the Restructuring Support Agreement (the "Original RSA") with certain senior note holders (collectively, the "Consenting Noteholders").

On February 5, 2021, the Debtors entered into the Amended Restructuring Support Agreement (the “Amended RSA”) with the Consenting Noteholders and certain revolving credit facility lenders (the “Consenting Lenders” and, together with the Consenting Noteholders, the “Consenting Creditors”), which contemplates that the Company will implement the restructuring through the Chapter 11 Cases pursuant to a plan of reorganization and the various related transactions set forth in or contemplated by the Amended RSA.

Holders of approximately 100% of the total commitments outstanding under our revolving credit facility and holders of approximately 72% of the aggregate amount of our Senior Notes outstanding are party to the Amended RSA.

See “ Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” to our consolidated financial statements included in "Item 8.

Financial Statements and Supplementary Data" for additional details regarding the Chapter 11 Cases and related items, the Amended RSA and our ability to continue as a going concern.

Chapter 11 Proceedings and Emergence from Chapter 11

On August 19, 2020 (the “Petition Date”), Valaris plc (“Legacy Valaris” or “Predecessor”) and certain of its direct and indirect subsidiaries (collectively, the “Debtors”) filed voluntary petitions for reorganization under chapter 11 of the Bankruptcy Code in the Bankruptcy Court under the caption In re Valaris plc, et al., Case No.

20-34114 (MI) (the “Chapter 11 Cases”).

On March 3, 2021, the Bankruptcy Court confirmed the Debtors' chapter 11 plan of reorganization.

In connection with the Chapter 11 Cases, on and prior to April 30, 2021 (the "Effective Date"), Legacy Valaris effectuated certain restructuring transactions, pursuant to which the successor company, Valaris, was formed and through a series of transactions Legacy Valaris transferred to a subsidiary of Valaris substantially all of the subsidiaries, and other assets, of Legacy Valaris.

On the Effective Date, we successfully completed our financial restructuring and together with the Debtors emerged from the Chapter 11 Cases.

Upon emergence from the Chapter 11 Cases, we eliminated $7.1 billion of debt and obtained a $520 million capital injection by issuing the first lien secured notes (the "First Lien Notes").

See “ Note 9 - Debt" for additional information on the First Lien Notes.

On the Effective Date, the Legacy Valaris Class A ordinary shares were cancelled and common shares of Valaris with a nominal value of $0.01 per share (the “Common Shares”) were issued.

Also, former holders of Legacy Valaris' equity were issued warrants (the "Warrants") to purchase Common Shares.

See “ Note 2 – Chapter 11 Proceedings” and " Note 3 - Fresh Start Accounting" to our consolidated financial statements included in "Item 8.

Financial Statements and Supplementary Data" for additional details regarding the reorganization, Chapter 11 Cases and related items.

Contract Drilling Operations

Our business consists of four operating segments:

(1) Floaters, which included our drillships and semisubmersible rigs, (2) Jackups, (3) ARO and (4) Other, which consists of management services on rigs owned by third-parties and the activities associated with our arrangements with ARO under the Rig Lease Agreements, the Secondment Agreement and the Transition Services Agreement.

Floaters, Jackups and ARO are also reportable segments.

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• term extension options, exercisable by our customers, upon advance notice to us, at mutually agreed, indexed, fixed rates or current rate at the date of extension,

• provisions permitting early termination of the contract (1) if the rig is lost or destroyed, (2) if operations are suspended for a specified period of time due to various events, including damage or breakdown of major rig equipment, unsatisfactory performance, or "force majeure" events or (3) at the convenience (without cause) of the customer (in certain cases obligating the customer to pay us an early termination fee providing some level of compensation to us for the remaining term),

• provisions permitting early termination of the contract (1) if the rig is lost or destroyed, (2) if operations are suspended for a specified period of time due to various events, including damage or breakdown of major rig equipment, unsatisfactory performance, or "force majeure" events (3) failure of the customer to receive final investment decision (FID) with respect to projects for which the drilling rig was contracted;

or (4) at the convenience (without cause) of the customer, exercisable upon advance notice to us, and in in certain cases without making an early termination payment to us,

• payment of compensation to us is (generally in U.S.

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• payment by us of the operating expenses of the drilling rig, including crew labor and incidental rig supply and maintenance costs,

• mobilization and demobilization requirements of us to move the drilling rig to and from the planned drilling site, and may include reimbursement of a portion of these moving costs by the customer in the form of an up-front payment, additional day rate over the contract term or direct reimbursement, and

• mobilization and demobilization requirements of us to move the drilling rig to and from the planned drilling site, and may include reimbursement of all or a portion of these moving costs by the customer in the form of an up-front payment, additional day rate over the contract term or direct reimbursement, and

• provisions allowing us to recover certain labor and other operating cost increases, including certain cost increases due to changes in applicable law, from our customers through day rate adjustment or direct reimbursement.

In general, following the downturn in offshore drilling demand commencing in 2014, contract awards have been subject to an extremely competitive bidding process.

The intense pressure on operating day rates has resulted in lower margin contracts that also contain less favorable contractual and commercial terms, including reduced or no mobilization and/or demobilization fees;

In general, in a downturn in offshore drilling demand, contract awards are subject to an extremely competitive bidding process.

The intense pressure on operating day rates could result in lower margin contracts that also contain less favorable contractual and commercial terms, including reduced or no mobilization and/or demobilization fees;

reduced day rates or zero day rates during downtime due to damage or failure of our equipment;

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Backlog Information

Our contract drilling backlog reflects commitments, represented by signed drilling contracts, and is calculated by multiplying the contracted day rate by the contract period.

The contracted day rate excludes certain types of lump sum fees for rig mobilization, demobilization, contract preparation, as well as customer reimbursables and bonus opportunities.

Contract backlog is adjusted for drilling contracts signed or terminated after each respective balance sheet date but prior to filing each of our annual reports on Form 10-K on March 2, 2021 and February 21, 2020, respectively.

Our backlog excludes ARO's backlog, but includes backlog from our rigs leased to ARO at the contractual rates, which are subject to adjustment by the shareholder agreement.

See " Note 5 - Equity Method Investment in ARO" to our consolidated financial statements included in "Item 8.

Financial Statements and Supplementary Data" for additional information.

The following table summarizes our contract backlog of business as of December 31, 2020 and 2019 (in millions):

Floaters $ 205.7 $ 847.3

Jackups 859.5 1,281.2

Total $ 1,205.3 $ 2,452.8

(1) Other includes the bareboat charter backlog for the nine jackup rigs leased to ARO to fulfill contracts between ARO and Saudi Aramco, in addition to backlog for our managed rig services.

Substantially all the operating costs for jackups leased to ARO through the bareboat charter agreements will be borne by ARO.

As of December 31, 2020, our backlog was $1.2 billion as compared to $2.5 billion as of December 31, 2019.

Our floater backlog declined $641.6 million and our jackup backlog declined $421.7 million.

Changes resulted from revenues realized during the period, contract terminations and contract suspensions, partially offset by new contract awards and contract extensions.

Our other segment backlog declined $184.2 million due to contract concessions and revenues realized during the period.

The following table summarizes our contract backlog of business as of December 31, 2020 and the periods in which such revenues are expected to be realized (in millions):

2021 2022 2023 2024

and Beyond Total

Floaters $ 205.7 $ — $ — $ — $ 205.7

Jackups 548.7 235.8 75.0 — 859.5

130.2 9.9 — — 140.1

Total $ 884.6 $ 245.7 $ 75.0 $ — $ 1,205.3

(1) Includes the bareboat charter backlog for the nine jackup rigs leased to ARO to fulfill contracts between ARO and Saudi Aramco, in addition to backlog for our managed rig services.

Substantially all the operating costs for jackups leased to ARO through the bareboat charter agreements will be borne by ARO.

Our drilling contracts generally contain provisions permitting early termination of the contract if the rig is lost or destroyed or by the customer if operations are suspended for a specified period of time due to breakdown of major rig equipment, unsatisfactory performance, "force majeure" events beyond the control of either party or other specified conditions.

In addition, our drilling contracts generally permit early termination of the contract by the customer for convenience (without cause), exercisable upon advance notice to us, and in some cases without making an early termination payment to us.

There can be no assurances that our customers will be able to or willing to fulfill their contractual commitments to us.

The amount of actual revenues earned and the actual periods during which revenues are earned will be different from amounts disclosed in our backlog calculations due to a lack of predictability of various factors, including unscheduled repairs, maintenance requirements, weather delays, contract terminations or renegotiations and other factors.

See "Item 1A.

Risk Factors - Our current backlog of contract drilling revenue may not be fully realized and may decline significantly in the future, which may have a material adverse effect on our financial position, results of operations and cash flows” and “Item 1A.

Risk Factors - We may suffer losses if our customers terminate or seek to renegotiate our contracts, if operations are suspended or interrupted or if a rig becomes a total loss.”

Management's Discussion and Analysis of Financial Condition and Results of Operations " for discussion on backlog information.

Drilling Contracts and Insurance Program

Our drilling contracts provide for varying levels of allocation of responsibility for liability between our customer and us for loss or damage to each party's property and third-party property, personal injuries and other claims arising out of our drilling operations.

We also maintain insurance for personal injuries, damage to or loss of property and certain business risks.

Our insurance policies typically consist of 12-month policy periods, and the next renewal date for a substantial portion of our insurance program is scheduled for May 31, 2021.

Our insurance program provides coverage, subject to the policies' terms and conditions and to the extent not otherwise assumed by the customer under the indemnification provisions of the drilling contract, for third-party claims arising from our operations, including third-party claims arising from well-control events, named windstorms, sudden and accidental pollution originating from our rigs, wrongful death and personal injury.

Third-party pollution claims could also arise from damage to adjacent pipelines and from spills of fluids maintained on the drilling rig.

Generally, our program provides liability coverage up to $750.0 million, with a per occurrence deductible of $10.0 million or less.

We retain the risk for liability not indemnified by the customer in excess of our insurance coverage.

Well-control events generally include an unintended release from a well that cannot be contained by using equipment on site (e.g., a blowout preventer), by increasing the weight of drilling fluid or by diverting the fluids safely into production facilities.

In addition to the third-party coverage described above, for claims relating to a

well-control event, we also have $150.0 million of coverage available to pay costs of controlling and re-drilling of the well and third-party pollution claims.

Our insurance program also provides coverage to us for physical damage (including total loss) to our rigs, excluding damage arising from a named windstorm in the U.S.

Gulf of Mexico.

This coverage is based on an agreed amount for each rig and has a per occurrence deductible for losses ranging from $15.0 million to $25.0 million.

Due to the significant premium, high deductible and limited coverage, we do not purchase windstorm insurance for our rigs in the U.S.

We also maintain insurance for these exposures to personal injuries, damage to or loss of property and certain business risks.

Our insurance program provides coverage that is customary for our industry.

Generally, our insurance program provides third-party liability coverage up to $750.0 million.

We retain the risk for liability not indemnified by the customer in excess of, and for risks not covered by, our insurance coverage.

Well-control events generally include an unintended release from a well that cannot be contained by using equipment on site, such as a blowout preventer, by increasing the weight of drilling fluid or by diverting the fluids safely into production facilities.

Our customers typically indemnify us for well-control events.

Our insurance program also provides hull and machinery coverage to us for physical damage (including total loss) to our rigs, cargo and equipment, excluding damage arising from a named windstorm in the U.S.

Gulf of Mexico.

Accordingly, we retain the risk for windstorm damage to our jackup and floater rigs in the U.S.

Accordingly, we retain the risk for windstorm damage to our drilling in the U.S.

Gulf of Mexico.

We do not currently carry insurance for loss of hire.

Any such lack of reimbursement may cause us to incur substantial costs.

Our drilling contracts customarily provide that each party is responsible for injuries or death to their respective personnel and loss or damage to their respective property (including the personnel and property of each parties’ contractors and subcontractors) regardless of the cause of the loss or damage.

However, in certain drilling contracts our customer’s responsibility for damage to its property and the property of its other contractors contains an exception to the extent the loss or damage is due to our negligence, which exception is usually subject to negotiated caps on a per occurrence basis, although in some cases we assume responsibility for all damages due to our negligence.

In addition, our drilling contracts typically provide for our customers to indemnify us, generally based on replacement cost minus some level of depreciation, for loss or damage to our down-hole equipment, and in some cases for a limited amount of the replacement cost of our subsea equipment, unless the damage is caused by our negligence, normal wear and tear or defects in our equipment.

In addition, our drilling contracts typically provide for our customers to indemnify us, generally based on replacement cost minus some level of depreciation, for loss or damage to our down-hole equipment, and in some cases for a limited amount of the repair of or replacement cost of our subsea equipment, unless the damage is caused by our negligence, normal wear and tear or defects in our equipment.

Subject to the exceptions noted below, our customers typically assume most of the responsibility for and indemnify us from any loss, damage or other liability resulting from pollution or contamination arising from operations, including as a result of blowouts, cratering and seepage, when the source of the pollution originates from the well or reservoir, including costs for clean-up and removal of pollution and third-party damages.

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Notwithstanding our negotiation of express limitations in our drilling contracts for losses or damages resulting from our ordinary negligence and any express limitations (albeit usually much higher) for losses or damages in the event of our gross negligence, under the applicable laws that govern certain of our drilling contracts, the courts will not enforce any indemnity for losses and damages that result from our gross negligence or willful misconduct.

and damages that result from our gross negligence or willful misconduct, regardless of any express limitation of our liability in the relevant drilling contracts.

As a result, under the laws of such jurisdictions, the indemnification provisions of our drilling contracts that would otherwise limit our liability in the event of our gross negligence or willful misconduct are deemed to be unenforceable as being contrary to public policy, and we are exposed to unlimited liability for losses and damages that result from our gross negligence or willful misconduct, regardless of any express limitation of our liability in the relevant drilling contracts.

Under the laws of certain jurisdictions, an indemnity from an operator for losses or damages of third-parties resulting from our gross negligence is enforceable, but an indemnity for losses or damages of the operator is not enforceable.

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Furthermore, although there is a lack of precedential authority for these types of claims in countries where the civil law is applied, in those situations where a fault based codified civil law system is applicable to our drilling contracts, as opposed to the common law system, the courts generally will not enforce a contractual indemnity clause that totally indemnifies us from losses or damages due to our gross negligence but may enforce the contractual indemnity over and above a cap on our liability for gross negligence, assuming the cap requires us to accept a significant amount of liability.

Similar to gross negligence, regardless of any express limitations in a drilling contract regarding our liability for fines and penalties and punitive damages, the laws of most jurisdictions will not enforce an indemnity that indemnifies a party for a fine or penalty that is levied or punitive damages that are assessed directly against such party on the ground that it is against public policy to indemnify a party from a fine and penalty or punitive damages, especially where the purpose of such levy or assessment is to deter the behavior that resulted in the fine or penalty or punish such party for the behavior that warranted the assessment of punitive damages.

Similar to gross negligence, regardless of any express limitations in a drilling contract regarding our liability for fines and penalties and punitive damages, the laws of most jurisdictions will not enforce an indemnity that indemnifies a party for a fine or penalty that is levied or punitive damages arising from willful misconduct that are assessed directly against such party on the ground that it is against public policy to indemnify a party from a fine, loss, penalty or punitive damages, especially where the purpose of such levy or assessment is to deter the behavior that resulted in the fine, loss or penalty or punish such party for the behavior that warranted the assessment of punitive damages.

The above description of our insurance program and the indemnification provisions of our drilling contracts is only a summary as of the date hereof and is general in nature.

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We provide our contract drilling services to major international, government-owned and independent oil and gas companies.

During 2020, our five largest customers accounted for 41% of consolidated revenues.

During the eight months ended December 31, 2021 (Successor), our five largest customers accounted for 42% of consolidated revenues.

BP, our only customer who accounts for 10% or more of consolidated revenues, accounted for 11% of consolidated revenues.

During the four months ended April 30, 2021 (Predecessor), our five largest customers accounted for 45% of consolidated revenues.

BP, our only customer who accounts for 10% or more of consolidated revenues, accounted for 14% of consolidated revenues.

The offshore contract drilling industry is highly competitive.

Drilling contracts are, for the most part, awarded on a competitive bid basis.

Price is often the primary factor in determining which contractor is awarded a

contract, although quality of service, operational and safety performance, equipment suitability and availability, location of equipment, reputation and technical expertise also are factors.

Price is often the primary factor in determining which contractor is awarded a contract, although quality of service, operational and safety performance, equipment suitability and availability, location of equipment, reputation and technical expertise also are factors.

There are numerous competitors with significant resources in the offshore contract drilling industry.

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In addition to potential increased liabilities, such legislative, judicial or regulatory action could impose increased financial, insurance or other requirements that may adversely impact the entire offshore drilling industry.

Additionally, environmental laws and regulations are revised frequently, and any changes, including changes in implementation or interpretation, that result in more stringent and costly waste handling, disposal and cleanup requirements for our industry could have a significant impact on our operating costs.

Additionally, environmental laws and regulations are revised frequently, and any changes, including changes in implementation or interpretation of existing laws/regulations, that result in more stringent and costly waste handling, disposal and cleanup requirements for our industry could have a significant impact on our operating costs.

The International Convention on Oil Pollution Preparedness, Response and Cooperation, the International Convention on Civil Liability for Oil Pollution Damage 1992, the U.K.

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Such statutes and related regulations impose a variety of obligations on us related to the prevention of oil spills, disposal of waste and liability for resulting damages.

For instance, OPA 90 imposes strict and, with limited

exceptions, joint and several liability upon each responsible party for oil removal costs as well as a variety of fines, penalties and damages.

For instance, OPA 90 imposes strict and, with limited exceptions, joint and several liability upon each responsible party for oil removal costs as well as a variety of fines, penalties and damages.

Similar environmental laws apply in our other areas of operation.

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As a result of the 2010 Macondo well incident, the United States Bureau of Safety and Environmental Enforcement ("BSEE") issued a drilling safety rule in 2012 that included requirements for the cementing of wells, well-control barriers, blowout preventers, well-control fluids, well completions, workovers and decommissioning operations.

BSEE also issued regulations requiring operators to have safety and environmental management systems ("SEMS") prior to conducting operations and requiring operators and contractors to agree on how the contractors will assist the operators in complying with the SEMS.

BSEE also issued regulations requiring operators to have safety and environmental management

systems ("SEMS") prior to conducting operations and requiring operators and contractors to agree on how the contractors will assist the operators in complying with the SEMS.

In addition, in August 2012, BSEE issued an Interim Policy Document ("IPD") stating that it would begin issuing Incidents of Non-Compliance to contractors as well as operators for serious violations of BSEE regulations.

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If this judicial precedent stands, it may reduce regulatory and civil litigation liability exposures.

In late 2014, the United States Coast Guard ("USCG") proposed new regulations that would impose GPS equipment and positioning requirements for drilling rigs operating in the U.S.

Gulf of Mexico and issued notices regarding the development of guidelines for cybersecurity measures used in the marine and offshore energy sectors for all vessels and facilities that are subject to the Maritime Transportation Security Act of 2002 ("MTSA"), including our rigs.

The regulations imposing GPS equipment and positioning requirements have not yet been issued.

In March 2020, the USCG issued its “Guidelines for Addressing Cyber Risks at MTSA Regulated Facilities” in order to assist facility owners and operators in complying with the requirements to assess, document, and address computer system or network vulnerabilities.

The MTSA regulations provide general requirements for regulated facility cybersecurity while allowing facility owners and operators the discretion to determine the details of how they will comply.

Facility owners and operators are responsible for assessing and documenting cybersecurity vulnerabilities and ensuring cybersecurity of their facilities under the Coast Guard’s oversight and guidance.

The Company is currently evaluating the new USCG guidelines and the extent to which the BSEE or other regulators will review our ability to address cybersecurity risks at MTSA-regulated facilities.

As the USCG provides further detail on how these guidelines will be implemented, we will address our cybersecurity program to comply with any regulations that are ultimately promulgated.

On July 28, 2016, BSEE adopted a new well-control rule that will be implemented in phases over the next several years (the "2016 Well Control Rule").

This new rule includes more stringent design requirements for well-control equipment used in offshore drilling operations.

On July 28, 2016, BSEE adopted the 2016 Well Control Rule.

This rule included more stringent design requirements for well-control equipment used in offshore drilling operations.

Subsequently, on May 2, 2019, BSEE issued the 2019 Well Control Rule, the revised well control and blowout preventer rule governing the Outer Continental Shelf (OCS) activities.

The new rule revised existing regulations impacting offshore oil and gas drilling, completions, workovers and decommissioning activities.

The rule revised existing regulations impacting offshore oil and gas drilling, completions, workovers and decommissioning activities.

Specifically, the 2019 Well Control Rule addresses six areas of offshore operations:

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The continuing and evolving threat of cyber attacks will likely require increased expenditures to strengthen cyber risk management systems for drilling rigs and onshore facilities.

For example, on May 11, 2017, an executive

order was issued entitled Strengthening the Cybersecurity of Federal Networks and Critical Infrastructure, which is intended to improve the nation's ability to defend against increasing and evolving cyber attacks, and in July 2017 the USCG issued proposed cybersecurity guidelines for port facilities and offshore facilities, including drilling rigs, that could be impacted by cyber attacks.

For example, on May 11, 2017, an executive order was issued entitled Strengthening the Cybersecurity of Federal Networks and Critical Infrastructure, which is intended to improve the nation's ability to defend against increasing and evolving cyber attacks, and in July 2017 the USCG issued proposed cybersecurity guidelines for port facilities and offshore facilities, including drilling rigs, that could be impacted by cyber attacks.

We cannot currently estimate the future expenditures associated with increased regulatory requirements, which may be material, and we continue to monitor regulatory changes as they occur.

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Consequently, legislation and regulatory programs to reduce greenhouse gas emissions could have an adverse effect on our financial position, operating results and cash flows.

Although the United States had withdrawn from the Paris Agreement in November 2020, the current Presidential Administration officially reentered the United States into the agreement in February 2021.

Although the United States had withdrawn from the Paris Agreement in November 2020, the United States officially reentered the agreement in February 2021.

Further, in November 2021, the Unites States and other countries entered into the Glasgow Climate Pact, which includes a range of measures designed to address climate change, including but not limited to the phase-out of fossil fuel subsidies, reducing methane emissions 30% by 2030, and cooperating toward the advancement of the development of clean energy.

It is likely that new executive orders, regulatory action, and/or legislation targeting greenhouse gas emissions, or prohibiting, restricting, or delaying oil and gas development activities in certain areas, will be proposed and/or promulgated.

For example, the current Presidential administration has issued multiple executive orders pertaining to environmental regulations and climate change, including the (1) Executive Order on Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis and (2) Executive Order on Tackling the Climate Crisis at Home and Abroad.

For example, multiple executive orders pertaining to environmental regulations and climate change have recently been issued, including the (1) Executive Order on Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis and (2) Executive Order on Tackling the Climate Crisis at Home and Abroad.

The latter executive order announced a moratorium on new oil and gas leasing on federal lands and offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices, established climate change as a primary foreign policy and national security consideration and affirmed that achieving net-zero greenhouse gas emissions by or before mid-century is a critical priority.

In June 2021, a federal judge for the U.S.

District Court of the Western District of Louisiana issued a nationwide preliminary injunction

against the pause of oil and natural gas leasing on public lands or in offshore waters while litigation challenging that aspect of the executive order is ongoing.

On January 27, 2022, the United States District Court for the District of Columbia found that the Bureau of Ocean Energy Management’s failure to calculate the potential emissions from foreign oil consumption violated the agency’s approval of oil and gas leases in the Gulf of Mexico under the National Environmental Policy Act.

The full impact of these federal actions, or any other future restrictions or prohibitions, remains unclear.

If new laws are enacted or other government actions are taken that restrict or prohibit offshore drilling in our principal areas of operation, impose additional regulatory (including environmental protection) requirements that materially increase the liabilities, financial requirements or operating or equipment costs associated with offshore drilling, exploration, development or production of oil and natural gas, or promote other sources of clean energy, our financial position, operating results and cash flows could be materially adversely affected.

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Revenues from non-U.S.

operations were 83%, 85% and 87% of our total consolidated revenues during 2020, 2019 and 2018, respectively.

operations and shipyard rig construction and enhancement projects are subject to political, economic and other uncertainties, including:

• terrorist acts, war and civil disturbances,

• expropriation, nationalization, deprivation or confiscation of our equipment or our customer's property,

• repudiation or nationalization of contracts,

• assaults on property or personnel,

• piracy, kidnapping and extortion demands,

• significant governmental influence over many aspects of local economies and customers,

• unexpected changes in law and regulatory requirements, including changes in interpretation or enforcement of existing laws,

• work stoppages, often due to strikes over which we have little or no control,

• complications associated with repairing and replacing equipment in remote locations,

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

• imposition of trade barriers,

• wage and price controls,

• import-export quotas,

• exchange restrictions,

• currency fluctuations,

• changes in monetary policies,

• uncertainty or instability resulting from hostilities or other crises in the Middle East, West Africa, Latin America or other geographic areas in which we operate,

• changes in the manner or rate of taxation,

• limitations on our ability to recover amounts due,

• increased risk of government and vendor/supplier corruption,

• increased local content requirements,

• the occurrence or threat of epidemic or pandemic diseases and any government response to such occurrence or threat,

• changes in political conditions, and

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

operations were 87%, 81%, 83% and 85% of our total consolidated revenues during eight months ended December 31, 2021 (Successor), four months ended April 30, 2021 (Predecessor), year-ended December 31, 2020 and 2019 (Predecessor), respectively.

See "Item 1A.

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Name Age Position

Thomas Burke 53 President and Chief Executive Officer

Jonathan Baksht 46 Executive Vice President and Chief Financial Officer

Anton Dibowitz 50 President and Chief Executive Officer

Darin Gibbins 40 Interim Chief Financial Officer and Vice President, Investor Relations and Treasurer

Gilles Luca 50 Senior Vice President - Chief Operating Officer

Alan Quintero 57 Senior Vice President - Business Development

McGuinty 58 Senior Vice President - General Counsel and Secretary

Set forth below is certain additional information on our executive officers, including the business experience of each executive officer for at least the last five years:

Thomas Burke became the President and Chief Executive Officer of Valaris and a member of the Board of Directors in April 2019 in connection with the Rowan Transaction.

Previously, he served as Rowan’s President and Chief Executive Officer as well as a director since April 2014.

He served as Rowan’s Chief Operating Officer beginning in July 2011 and was appointed President in March 2013.

Burke first joined Rowan in December 2009, serving as Chief Executive Officer and President of LeTourneau Technologies until the sale of LeTourneau in June 2011.

From 2006 to 2009, Mr.

Burke was a Division President at Complete Production Services, an oilfield services company, and from 2004 to 2006, served as its Vice President for Corporate Development.

Burke received his PhD in Engineering from Trinity College at the University of Oxford, a Bachelor of Science in Engineering with Honors from Heriot-Watt University in Scotland, and an MBA from Harvard Business School, where he was awarded a Baker Scholarship.

Jonathan Baksht became Executive Vice President and Chief Financial Officer of Valaris in June 2019.

Previously, he served as the Company's Senior Vice President - Chief Financial Officer since November 2015, and as Vice President - Finance and Vice President - Treasurer before his appointment as Chief Financial Officer.

Prior to joining Valaris in August 2013, Mr.

Baksht served as a Senior Vice President at Goldman Sachs & Co.

within the Investment Banking Division where he served as a financial advisor to energy clients, oilfield services lead and a member of the Merger & Acquisitions Group.

Prior to joining Goldman Sachs in 2006, he consulted on strategic initiatives for energy clients at Andersen Consulting.

Baksht holds a Master of Business Administration from the Kellogg School of Management at Northwestern University and a Bachelor of Science with High Honors in Electrical Engineering from the University of Texas at Austin.

Anton Dibowitz became the President and Chief Executive Officer of Valaris in December 2021, following his service as the Company’s interim President and Chief Executive Officer since September 2021.

Previously, he served as an advisor of Seadrill Ltd.

from November 2020 until March 2021.

He served as Chief Executive Officer of Seadrill Ltd.

from July 2017 until October 2020.

Prior to this Mr.

Dibowitz served as Executive Vice President of Seadrill Management since June 2016, and as Chief Commercial Officer since January 2013.

He has over 20 years of drilling industry experience.

Prior to joining Seadrill, Mr.

Dibowitz held various positions within tax, process reengineering and marketing at Transocean Ltd.

and Ernst & Young LLP.

He is a Certified Public Accountant and a graduate of the University of Texas at Austin where he received a Bachelor's degree in Business Administration, and Master's degrees in Professional Accounting (MPA) and Business Administration (MBA).

Darin Gibbins became the Interim Chief Financial Officer and Vice President, Investor Relations and Treasurer of Valaris in September 2021.

Previously, he served as Vice President, Investor Relations and Treasurer of the Company since June 2020 and has also served as Vice President, Treasurer of the Company from April 2019 through June 2020.

Prior to joining the Company, he spent over thirteen years at Rowan Companies plc, beginning in November 2006.

At Rowan Companies plc, he most recently served as Vice President, FP&A and Treasurer from February 2017 to April 2019 and Treasurer & Director, Financial Planning from March 2016 through February 2017.

Gibbins also worked as a Senior Consultant at Protiviti Inc.

from August 2004 through November 2006.

Gibbins is a graduate of the University of Texas at Austin, where he earned his Bachelor of Business Administration (BBA) in Finance with a minor in Accounting.

Gilles Luca joined Valaris in 1997 and was appointed to his current position of Senior Vice President - Chief Operating Officer in November 2019.

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He holds a Master's Degree in Petroleum Engineering from the French Petroleum Institute and a Bachelor in Civil Engineering from ESTP, Paris.

Alan Quintero became Senior Vice President - Business Development of Valaris in April 2019 in connection with the Rowan Transaction.

Previously, he served as Rowan’s Senior Vice President, Business Development since 2018, after joining Rowan as Senior Vice President, Chief Technology Officer in 2017.

Prior to joining Rowan, Mr.

Quintero was a Partner at Trenegy Incorporated, a management consulting firm, from January 2016 to June 2017, and spent more than 20 years in various operational and managerial roles for international offshore drilling companies including serving as Senior Vice President, Operations at Transocean.

Quintero received a Bachelor of Science in Mechanical Engineering from Texas A&M University.

He also received education at Heriot-Watt University, Columbia University, Harvard University and the Wharton School of Business.

McGuinty joined Valaris in February 2016 as Senior Vice President - General Counsel and Secretary.

Prior to joining Valaris, Mr.

McGuinty served as General Counsel and Company Secretary of Abu Dhabi

National Energy Company from January 2014 to December 2015.

Previously, Mr.

McGuinty spent 18 years with Schlumberger where he held various senior legal management positions in the United States, Europe and the Middle East including Director of Compliance, Deputy General Counsel - Corporate and M&A and Director of Legal Operations.

Prior to Schlumberger, Mr.

McGuinty practiced corporate and commercial law in Canada and France.

McGuinty holds a Bachelor of Laws and Bachelor of Civil Law from McGill University and a Bachelor of Social Sciences from the University of Ottawa.

We employed approximately 4,900 personnel worldwide including contract employees, and approximately 3,400 personnel excluding contract employees, as of December 31, 2021.

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In that event, the trading price of our securities could decline, and you could lose all or part of your investment.

Risks Related to Chapter 11 Proceedings

• Operating under the Bankruptcy Court protection for a long period of time may harm our business.

• We may not be able to obtain confirmation of a plan of reorganization.

• We have substantial liquidity needs and may not be able to obtain sufficient liquidity for the duration of the Chapter 11 Cases or to confirm a plan of reorganization or liquidation.

• As a result of the Chapter 11 Cases, our financial results may be volatile and may not reflect historical trends.

• We may be subject to claims that will not be discharged in the Chapter 11 Cases.

• Our actual financial results may vary significantly from the projections filed with the Bankruptcy Court.

• The pursuit of the Chapter 11 Cases has consumed and will continue to consume a substantial portion of the time and attention of our management, and we may face increased levels of employee attrition.

• Trading in our securities during the pendency of the Chapter 11 Cases is highly speculative and poses substantial risks.

• In certain instances, a chapter 11 case may be converted to a case under chapter 7 of the Bankruptcy Code.

• Any plan of reorganization that we may implement will be based in large part upon assumptions and analyses developed by us.

If these assumptions and analyses prove to be incorrect, our plan may be unsuccessful in its execution.

• We may not be able to achieve our stated goals and continue as a going concern under a plan of reorganization.

• Our ability to use our net operating loss carryforwards ("NOLs") may be limited by changes in ownership due to the Chapter 11 Cases.

Risks Related to Our Business, Operations and Market Conditions

• The COVID-19 pandemic and recent developments in the oil and gas industry could adversely impact our financial condition and results of operations.

• The success of our business largely depends on the level of activity in the oil and gas industry, which can be significantly affected by volatile oil and natural gas prices.

Risks Related to Our Business, Operations, Indebtedness and Market Conditions

• The effects of the COVID-19 pandemic have adversely impacted, and could continue to adversely impact, our financial condition and results of operations.

• The success of our business largely depends on the level of activity in the oil and gas industry, which can be significantly affected by oil and natural gas prices.

• The offshore contract drilling industry historically has been highly competitive and cyclical, with periods of low demand and excess rig availability that could result in adverse effects on our business.

• Our business will be adversely affected if we are unable to secure contracts on economically favorable terms or if option periods in existing contracts are not exercised as expected.

• We have a significant amount of debt.

Our debt levels and debt agreement restrictions may limit our liquidity, our ability to obtain additional financing and our pursuit of other business opportunities.

• Our current backlog of contract drilling revenue may not be fully realized and may decline significantly in the future.

• Our business will be adversely affected if we are unable to secure contracts on economically favorable terms.

• Our customers may be unable or unwilling to fulfill their contractual commitments to us, including their obligations to pay for losses, damages or other liabilities.

• We may suffer losses if our customers terminate or seek to renegotiate our contracts, if operations are suspended or interrupted or if a rig becomes a total loss.

• We may incur impairments as a result of future declines in demand for offshore drilling rigs.

• The loss of a significant customer or customer contract could adversely affect us.

• Our current backlog of contract drilling revenue may not be fully realized and may decline significantly in the future .

• We may not realize the expected benefits of the ARO joint venture, which depends on a single customer for its income and accounts receivable, and our inability to realize such benefits may introduce additional risks to our business.

• We have taken, and continue to take, cost-reduction actions, which may not be successful.

• We may have difficulty obtaining or maintaining insurance in the future on terms we find acceptable and our insurance coverage may not protect us against all of the risks and hazards we face, including those specific to offshore operations.

• The potential for U.S.

Gulf of Mexico hurricane related windstorm damage or liabilities could result in uninsured losses and may cause us to alter our operating procedures during hurricane season.

• Our drilling contracts with national oil companies may expose us to greater risks than we normally assume in drilling contracts with non-governmental customers.

• Geopolitical events and violence could affect the markets for our services and have a material adverse effect on our business and cost and availability of insurance.

• Rig construction, upgrade, enhancement and reactivation projects are subject to risks, including delays and cost overruns, which could have a material adverse effect on our financial position, operating results or cash flows.

• The loss of a significant customer or customer contract, as well as customer consolidation and changes to customer strategy, could adversely affect us.

• Rig reactivation, upgrade and enhancement projects are subject to risks, including delays and cost overruns.

• We have historically made significant expenditures to maintain our fleet to comply with laws and the applicable regulations and standards of governmental authorities and organizations, or to expand our fleet, and we may be required to make significant capital expenditures to maintain our competitiveness.

• Failure to recruit and retain skilled personnel could adversely affect our business.

• We have historically made significant capital expenditures to maintain our fleet to comply with laws and the applicable regulations and standards of governmental authorities and organizations, or to expand our fleet, and we may be required to make significant capital expenditures to maintain our competitiveness.

• Unionization efforts and labor regulations in certain countries in which we operate could materially increase our costs or limit our flexibility.

• Our shared service center may not create the operational efficiencies that we expect, and may create risks relating to the processing of transactions and recording of financial information.

• We may not realize the expected benefits of ARO, which depends on a single customer for its income and accounts receivable.

• Our information technology systems, including rig operating systems, are subject to cybersecurity risks.

• We may have difficulty obtaining or maintaining insurance in the future on terms we find acceptable and our insurance coverage cannot protect us against all of the risks and hazards we face.

• The potential for hurricane related windstorm damage or liabilities could result in uninsured losses.

• Geopolitical events and violence could affect the markets for our services and have a material adverse effect on our business and cost and availability of insurance.

• Our drilling contracts with national oil companies may expose us to greater risks than we normally assume in drilling contracts with non-governmental customers.

• Unionization efforts and labor regulations in certain countries in which we operate could materially increase our costs or limit our flexibility with regard to the management of our personnel.

• Significant part or equipment shortages, supplier capacity constraints, supplier production disruptions, supplier quality and sourcing issues or price increases could increase our operating costs, decrease our revenues and adversely impact our operations.

• We may incur impairments as a result of future declines in demand for offshore drilling rigs.

• Our long-term contracts are subject to the risk of cost increases, which could adversely affect our profitability.

• Our information technology systems, including rig operating systems, are subject to cybersecurity risks and threats.

Risks Related to Our Indebtedness and Ordinary Shares

• Our Class A ordinary shares have been delisted from the NYSE.

• The accounting method for our 2024 Convertible Notes could have a material effect on our reported financial results.

• Transfers of our Class A ordinary shares may be subject to stamp duty or stamp duty reserve tax ("SDRT") in the U.K., which would increase the cost of dealing in our Class A ordinary shares.

• If our Class A ordinary shares are not eligible for continued deposit and clearing within the facilities of DTC, then transactions in our securities may be disrupted.

• We have less flexibility as a U.K.

public limited company with respect to certain aspects of capital management than U.S.

corporations due to increased shareholder approval requirements.

• Our articles of association contain anti-takeover provisions;

however, the Company is not subject to the U.K.'s City Code on Takeovers and Mergers.

• English law requires that we meet certain additional financial requirements before declaring dividends and returning funds to shareholders.

Legal, Regulatory and Tax Risks

• Failure to comply with anti-bribery statutes, such as the U.S.

Foreign Corrupt Practices Act and the U.K.

Bribery Act, could result in fines, criminal penalties, drilling contract terminations and an adverse effect on our business.

• Increasing regulatory complexity could adversely impact the costs associated with our offshore drilling operations and reduce demand.

• Compliance with or breach of environmental laws can be costly and could limit our operations.

• Our ability to pay our operating and capital expenses and make payments due on our debt depends on many factors beyond our control.

• The Indenture (as defined below) governing the First Lien Notes contains operating and financial restrictions that restrict our business and financing activities.

• On April 30, 2021, we emerged from bankruptcy, which may adversely affect our business and relationships.

• Our actual financial results after emergence from bankruptcy may not be comparable to our projections filed with the Bankruptcy Court in the course of the Chapter 11 Cases.

• Our historical financial information will not be indicative of future financial performance as a result of the implementation of the plan of reorganization and the transactions contemplated thereby, as well as our application of fresh start accounting following emergence.

• The exercise of all or any number of outstanding warrants or the issuance of stock-based awards may dilute the holders of our Common Shares.

• Regulation of greenhouse gases and climate change could have a negative impact on our business.

• The IRS may not agree with the conclusion that we should be treated as a foreign corporation for U.S.

• Consumer preferences for alternative fuels and electric-powered vehicles, as part of the global energy transition, may lead to reduced demand for our services.

• Increased scrutiny from stakeholders and others regarding our ESG practices and reporting responsibilities could result in additional costs or risks and adversely impact our business and reputation.

Regulatory, Legal and Tax Risks

• Failure to comply with anti-bribery statutes could result in fines, criminal penalties, drilling contract terminations and have an adverse effect on our business.

• Increasing regulatory complexity could adversely impact our offshore drilling operations and reduce demand.

• Compliance with or breach of environmental laws could be costly and limit our operations.

• The Internal Revenue Service ("IRS") may not agree with the conclusion that we should be treated as a foreign corporation for U.S.

federal tax purposes.

tax laws and IRS guidance could affect our ability to engage in certain acquisition strategies and certain internal restructurings.

tax laws and IRS guidance could affect our ability to engage in certain transactions.

• Governments may pass laws that subject us to additional taxation or may challenge our tax positions.

• Our consolidated effective income tax rate may vary substantially over time.

• Investor enforcement of civil judgments against us may be more difficult.

• The rights of our shareholders are governed under Bermuda law, and as a result, holders of our Common Shares may have difficulty enforcing civil judgments against us.

• Our bye-laws restrict shareholders from bringing legal action against our officers and directors.

• Provisions in our bye-laws could delay or prevent a change in control of our company.

• Our business could be affected as a result of activist investors.

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operations involve additional risks not typically associated with U.S.

• The U.K.'s withdrawal from the E.U.

may have a negative effect on economic conditions, financial markets and our business.

• Legislation enacted in Bermuda as to Economic Substance may affect our operations.

• The impact of the U.K.'s withdrawal from the E.U.

on economic conditions may affect our business.

Compared sentence by sentence after normalising whitespace, quotation marks, case and digits, so re-formatting and restated figures do not read as changed language. Wording changes appear as one removal and one addition. The current filing and the prior one are authoritative.

What changed 10-K

Item 1. Business