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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
  Washington, D.C. 20549  
 


FORM 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE 
SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2019
 
OR
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 1-8097
Valaris plc
(Exact name of registrant as specified in its charter)

England and Wales
 
98-0635229
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
 
 
 
 
110 Cannon Street
London, England            EC4N6EU
(Address of principal executive offices)        (Zip Code)

Registrant's telephone number, including area code: +44 (0) 20 7659 4660
 
Securities registered pursuant to Section 12(b) of the Act:

 
Title of each class
 
Ticker Symbol(s)
 
Name of each exchange on which registered
Class A ordinary shares, U.S. $0.40 par value
 
VAL
 
New York Stock Exchange
4.70% Senior Notes due 2021
 
VAL21
 
New York Stock Exchange
4.50% Senior Notes due 2024
 
VAL24
 
New York Stock Exchange
8.00% Senior Notes due 2024
 
VAL24A
 
New York Stock Exchange
5.20% Senior Notes due 2025
 
VAL25A
 
New York Stock Exchange
7.75% Senior Notes due 2026
 
VAL26
 
New York Stock Exchange
5.75% Senior Notes due 2044
 
VAL44
 
New York Stock Exchange

Securities registered pursuant to Section 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 (S232.405 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 emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act (Check one):

Large accelerated filer
 
x
 
  
Accelerated filer
 
o
 
 
 
 
 
 
 
 
Non-Accelerated filer
 
o
 
  
Smaller reporting company
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Emerging growth company
 
 
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 is a shell company (as defined in Rule 12b-2 of the Act).
Yes         No
 
The aggregate market value of the Class A ordinary shares (based upon the closing price on the New York Stock Exchange on June 30, 2019 of $8.73 of Valaris plc held by non-affiliates of Valaris plc at that date was approximately $21,353,000
 
As of February 17, 2020, there were 197,280,817 Class A ordinary shares of Valaris plc issued and outstanding.
 
DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Company's Proxy Statement for the 2020 General Meeting of Shareholders are incorporated by reference into Part III of this report.




 
 
 
 
TABLE OF CONTENTS
 
 
 
 
 
 
 
 
PART I
ITEM 1.
5
 
ITEM 1A.
16
 
ITEM 1B.
42
 
ITEM 2.
43
 
ITEM 3.
46
 
ITEM 4.
47
 
 
 
 
 
 
 
 
PART II
ITEM 5.
 
48
 
ITEM 6.
 
54
 
ITEM 7.
 
55
 
ITEM 7A.
 
87
 
ITEM 8.
 
87
 
ITEM 9.
 
168
 
ITEM 9A.
 
168
 
ITEM 9B.
168
 
 
 
 
 
PART III
ITEM 10.
169
 
ITEM 11.

169
 
ITEM 12.
170
 
ITEM 13.

171
 
ITEM 14.

171
 
 
 
 
 
 
 
 
PART IV
ITEM 15.
 
172
 
ITEM 16.
 
180
 
 
SIGNATURES
181





FORWARD-LOOKING STATEMENTS
 
Statements contained in this report that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act").  Forward-looking statements include words or phrases such as "anticipate," "believe," "estimate," "expect," "intend," "likely," "plan," "project," "could," "may," "might," "should," "will" and similar words and specifically include statements regarding expected financial performance; synergies and expected additional cost savings; dividends; expected utilization, day rates, revenues, operating expenses, cash flow, contract terms, contract backlog, capital expenditures, insurance, financing and funding; expected work commitments, awards and contracts; the timing of availability, delivery, mobilization, contract commencement or relocation or other movement of rigs and the timing thereof; future rig construction (including work-in-progress and completion thereof), enhancement, upgrade or repair and timing and cost thereof; the suitability of rigs for future contracts; the offshore drilling market, including supply and demand, customer drilling programs, stacking of rigs, effects of new rigs on the market and effects of declines in commodity prices; performance of our joint venture with Saudi Arabian Oil Company ("Saudi Aramco"); expected divestitures of assets; general market, business and industry conditions, trends and outlook; future operations; the impact of increasing regulatory complexity; the outcome of tax disputes, assessments and settlements; our program to high-grade the rig fleet by investing in new equipment and divesting selected assets and underutilized rigs; expense management; and the likely outcome of litigation, legal proceedings, investigations or insurance or other claims or contract disputes and the timing thereof.

Such statements are subject to numerous risks, uncertainties and assumptions that may cause actual results to vary materially from those indicated, particularly in light of our projected negative cash flows in 2020 and highly leveraged balance sheet, including:
 
our ability to successfully integrate the business, operations and employees of Rowan Companies Limited (formerly Rowan Companies plc) ("Rowan") and the Company (as defined herein) to realize synergies and cost savings in connection with the Rowan Transaction (as defined herein);

changes in future levels of drilling activity and capital expenditures by our customers, whether as a result of global capital markets and liquidity, prices of oil and natural gas or otherwise, which may cause us to idle or stack additional rigs;

changes in worldwide rig supply and demand, competition or technology, including as a result of delivery of newbuild drilling rigs;

downtime and other risks associated with offshore rig operations, including rig or equipment failure, damage and other unplanned repairs, the limited availability of transport vessels, hazards, self-imposed drilling limitations and other delays due to severe storms and hurricanes and the limited availability or high cost of insurance coverage for certain offshore perils, such as hurricanes in the Gulf of Mexico or associated removal of wreckage or debris;

governmental action, terrorism, piracy, military action and political and economic uncertainties, including uncertainty or instability resulting from the U.K.'s withdrawal from the European Union, civil unrest, political demonstrations, mass strikes, or an escalation or additional outbreak of armed hostilities or other crises in oil or natural gas producing areas of the Middle East, North Africa, West Africa or other geographic areas, which may result in expropriation, nationalization, confiscation or deprivation or destruction of our assets; or suspension and/or termination of contracts based on force majeure events or adverse environmental safety events;

risks inherent to shipyard rig construction, repair, modification or upgrades, unexpected delays in equipment delivery, engineering, design or commissioning issues following delivery, or changes in the commencement, completion or service dates;

2




possible cancellation, suspension, renegotiation or termination (with or without cause) of drilling contracts as a result of general and industry-specific economic conditions, mechanical difficulties, performance or other reasons;

our ability to enter into, and the terms of, future drilling contracts, including contracts for our newbuild units and acquired rigs, for rigs currently idled and for rigs whose contracts are expiring;

any failure to execute definitive contracts following announcements of letters of intent, letters of award or other expected work commitments;

the outcome of litigation, legal proceedings, investigations or other claims or contract disputes, including any inability to collect receivables or resolve significant contractual or day rate disputes, any renegotiation, nullification, cancellation or breach of contracts with customers or other parties and any failure to execute definitive contracts following announcements of letters of intent;

governmental regulatory, legislative and permitting requirements affecting drilling operations, including limitations on drilling locations (such as the Gulf of Mexico during hurricane season) and regulatory measures to limit or reduce greenhouse gases;

potential impacts on our business resulting from climate-change or greenhouse gas legislation or regulations, and the impact on our business from climate-change related physical changes or changes in weather patterns;

new and future regulatory, legislative or permitting requirements, future lease sales, changes in laws, rules and regulations that have or may impose increased financial responsibility, additional oil spill abatement contingency plan capability requirements and other governmental actions that may result in claims of force majeure or otherwise adversely affect our existing drilling contracts, operations or financial results;

our ability to attract and retain skilled personnel on commercially reasonable terms, whether due to labor regulations, unionization or otherwise;

environmental or other liabilities, risks, damages or losses, whether related to storms, hurricanes or other weather-related events (including wreckage or debris removal), collisions, groundings, blowouts, fires, explosions, other accidents, terrorism or otherwise, for which insurance coverage and contractual indemnities may be insufficient, unenforceable or otherwise unavailable;

our ability to obtain financing, service our indebtedness, fund negative cash flow and capital expenditures and pursue other business opportunities may be limited by our significant debt levels, debt agreement restrictions and the credit ratings assigned to our debt by independent credit rating agencies;

the adequacy of sources of liquidity for us and our customers;

tax matters, including our effective tax rates, tax positions, results of audits, changes in tax laws, treaties and regulations, tax assessments and liabilities for taxes;

our ability to realize the expected benefits of our joint venture with Saudi Aramco, including our ability to fund any required capital contributions;

delays in contract commencement dates or the cancellation of drilling programs by operators;

activism by our security holders;


3



economic volatility and political, legal and tax uncertainties following the June 23, 2016, vote in the U.K. to exit from the European Union;

the occurrence of cybersecurity incidents, attacks or other breaches to our information technology systems, including our rig operating systems;

adverse changes in foreign currency exchange rates, including their effect on the fair value measurement of our derivative instruments;

the occurrence or threat of epidemic or pandemic diseases and any government response to such occurrence or threat and the impacts of such events on oil prices and the demand for offshore drilling services; and

potential long-lived asset impairments, including the impact of any impairment on our compliance with debt covenants.

In addition to the numerous risks, uncertainties and assumptions described above, you should also carefully read and consider "Item 1A. Risk Factors" in Part I and "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations" in Part II of this Form 10-K.  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, except as required by law.

4



PART I

Item 1.  Business

General

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.

We are a leading provider of offshore contract drilling services to the international oil and gas industry. Exclusive of two rigs under construction and one rig marked for retirement and classified as held-for-sale, we currently own and operate an offshore drilling rig fleet of 74 rigs, with drilling operations in almost every major offshore market across six continents. Inclusive of rigs under construction, our fleet includes 16 drillships, eight dynamically positioned semisubmersible rigs, two moored semisubmersible rigs and 50 jackup rigs, nine of which are leased to our 50/50 joint venture with Saudi Aramco. We operate the world's largest fleet of offshore drilling rigs, including one of the newest ultra-deepwater fleets in the industry and a leading premium jackup fleet.

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 24 countries on six continents. The markets in which we operate include the Gulf of Mexico, Brazil, the Mediterranean, the North Sea, Norway, the Middle East, West Africa, Australia and Southeast Asia.

We provide drilling services on a day rate contract basis. Under day rate contracts, we provide an integrated service that includes the provision of a drilling rig and rig crews for which we receive a daily rate that may vary between the full rate and zero rate throughout the duration of the contractual term, depending on the operations of the rig. We also may receive lump-sum fees or similar compensation for the mobilization, demobilization and capital upgrades of our rigs. 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.

The decline in oil prices from 2014 highs led to a significant reduction in global demand for offshore drilling services. Customers significantly reduced their capital spending budgets, including the cancellation or deferral of existing programs, resulting in fewer contracting opportunities for offshore drilling rigs. Declines in capital spending levels, together with the oversupply of rigs from newbuild deliveries, resulted in significantly reduced day rates and utilization that led to one of the most severe downturns in the industry's history.

More recently, oil prices have increased meaningfully from the decade lows reached during 2016, leading to signs of a gradual recovery in demand for offshore drilling services. However, macroeconomic and geopolitical headwinds triggered a decline in Brent crude prices in late 2018. In 2019, oil prices experienced a gradual recovery before falling again in early 2020.

While this market volatility will likely continue over the near-term, we continue to observe improvements in the shallow-water market, particularly with respect to higher-specification rigs, as higher levels of customer demand and rig retirements have led to gradually increasing jackup utilization over the past year. However, the timing and extent of this improvement is uncertain. Moreover, global floater utilization has increased as compared to a year ago due to a higher number of contracted rigs and lower global supply resulting from rig retirements. However, the floater recovery has lagged the jackup recovery as average contract durations remain relatively short-term and pricing improvements to date have been modest.

Despite the recent increase in customer activity, contract awards remain subject to an extremely competitive bidding process, and the corresponding pressure on operating day rates in recent periods has resulted in low margin contracts, particularly for floaters. Therefore, our results from operations may continue to decline over the near-term as current contracts with above-market rates expire and new contracts are executed at lower rates. We believe further

5



improvements in demand coupled with a reduction in rig supply are necessary to improve the commercial landscape for day rates.

Valaris plc is a public limited company incorporated under the laws of England and Wales in 2009. Our principal executive office is located at 110 Cannon Street, London EC4N6EU, England, United Kingdom, and our telephone number is +44 (0) 20 7659 4660.  Our website is www.valaris.com.  Information contained on our website is not included as part of, or incorporated by reference into, this report.

Rowan Transaction

On October 7, 2018, we entered into a transaction agreement (the "Transaction Agreement") with Rowan, and on April 11, 2019 (the "Transaction Date"), we completed our combination with Rowan pursuant to the Transaction Agreement (the "Rowan Transaction") and changed our name to Ensco Rowan plc. On July 30, 2019, we changed our name to Valaris plc. Rowan's financial results are included in our consolidated results beginning on the Transaction Date.

As a result of the Rowan Transaction, Rowan shareholders received 2.750 Valaris Class A ordinary shares for each Rowan Class A ordinary share, representing a value of $43.67 per Rowan share based on a closing price of $15.88 per Valaris share on April 10, 2019, the last trading day before the Transaction Date. Total consideration delivered in the Rowan Transaction consisted of 88.3 million Valaris shares with an aggregate value of $1.4 billion. All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split (as defined herein).

Prior to the Rowan Transaction, Rowan and Saudi Aramco formed a 50/50 joint venture to own, manage and operate drilling rigs offshore Saudi Arabia ("Saudi Aramco Rowan Offshore Drilling Company" or "ARO"). ARO currently owns a fleet of seven jackup rigs, leases another nine jackup rigs from us and has plans to purchase up to 20 newbuild jackup rigs over an approximate 10 year period. In January 2020, ARO ordered the first two newbuild jackups scheduled for delivery in 2022. The rigs we lease to ARO are done so through bareboat charter agreements whereby substantially all operating costs are incurred by ARO. All nine jackup rigs leased to ARO and all seven ARO-owned jackup rigs are under long-term contracts with Saudi Aramco. For additional information about our ARO joint venture, See Note 4 of our consolidated financial statements included in Item 8 of this annual report.

The Rowan Transaction enhanced the market leadership of the combined company with a fleet of high-specification floaters and jackups and positions us well to meet increasing and evolving customer demand. The increased scale, diversification and financial strength of the combined company provides us advantages to better serve our customers. Exclusive of two older jackup rigs marked for retirement, Rowan’s offshore rig fleet at the Transaction Date consisted of four ultra-deepwater drillships and 19 jackup rigs.

Reverse Stock Split

Upon closing of the Rowan Transaction, we effected a consolidation (being a reverse stock split under English law) where every four existing Valaris Class A ordinary shares, each with a nominal value of $0.10, were consolidated into one Class A ordinary share, each with a nominal value of $0.40 (the "Reverse Stock Split"). Our shares began trading on a reverse stock split-adjusted basis on April 11, 2019. All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split.

Contract Drilling Operations        

Prior to the Rowan Transaction, our business consisted of three operating segments: (1) Floaters, which included our drillships and semisubmersible rigs, (2) Jackups and (3) Other, which consisted of management services on rigs owned by third-parties. Our Floaters and Jackups were also reportable segments.


6



As a result of the Rowan Transaction, we concluded that we would maintain the aforementioned segment structure while adding ARO as a reportable segment for the new combined company. We also concluded that the activities associated with our arrangements with ARO, consisting of our Transition Services Agreement, Rig Lease Agreements and Secondment Agreement, do not constitute reportable segments and are therefore included within Other in our segment disclosures. See Note 4 for additional information on ARO and related arrangements.
  
Of our 76 rigs (excluding held-for-sale rigs), 37 are located in the Middle East, Africa and Asia Pacific (including two rigs under construction), 18 are located in North and South America and 21 are located in Europe and the Mediterranean as of December 31, 2019.
 
Our drilling rigs drill and complete oil and natural gas wells. From time to time, our drilling rigs may be utilized as accommodation units or for non-drilling services, such as workovers and interventions, plug and abandonment and decommissioning work. Demand for our drilling services is based upon many factors beyond our control. See “Item 1A. Risk Factors - 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.”

Our drilling contracts are the result of negotiations with our customers, and most contracts are awarded upon competitive bidding. The terms of our drilling contracts can vary significantly, but generally contain the following commercial terms:

contract duration or term for a specific period of time or a period necessary to drill one or more wells, 

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 (i) if the rig is lost or destroyed, (ii) 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 (iii) 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),

payment of compensation to us is (generally in U.S. dollars although some contracts require a portion of the compensation to be paid in local currency) on a day rate basis such that we receive a fixed amount for each day that the drilling unit is under contract (lower day rates generally apply for limited periods when operations are suspended due to various events, including during delays that are beyond our reasonable control, during repair of equipment damage or breakdown and during periods of re-drilling damaged portions of the well, and no day rate, or zero rate, generally applies when these limited periods are exceeded until the event is remediated, and during periods to remediate unsatisfactory performance or other specified conditions), 

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

mobilization and demobilization requirements of us to move the drilling unit 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

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.    


7



In general, following the downturn in offshore drilling demand commencing in 2014, recent 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; reduced day rates or zero day rates during downtime due to damage or failure of our equipment; reduced standby, redrill and moving rates and reduced periods in which such rates are payable; reduced caps on reimbursements for lost or damaged downhole tools; reduced periods to remediate downtime due to equipment breakdowns or failure to perform in accordance with the contractual standards of performance before the operator may terminate the contract; certain limitations on our ability to be indemnified from operator and third party damages caused by our fault, resulting in increases in the nature and amounts of liability allocated to us; and reduced or no early termination fees and/or termination notice periods.

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 February 21, 2020 and February 28, 2019, respectively. Our backlog excludes ARO's backlog, but includes bareboat charter and related revenue for the jackup rigs leased to ARO.

The following table summarizes our contract backlog of business as of December 31, 2019 and 2018 (in millions):
 
2019
 
2018
Floaters
$
847.3

 
$
941.5

Jackups
1,281.2

 
1,071.0

Other(1)
324.3

 
169.9

Total
$
2,452.8

 
$
2,182.4


(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, 2019, our backlog was $2.5 billion as compared to $2.2 billion as of December 31, 2018. Our floater backlog declined $94.2 million and our jackup backlog increased $210.2 million. Changes resulted from revenues realized during the period, partially offset by the addition of backlog from the Rowan Transaction, new contract awards and contract extensions. Our other segment backlog increased $154.4 million due to the addition of backlog from the Rowan Transaction related to the rigs leased to ARO.
    

8



The following table summarizes our contract backlog of business as of December 31, 2019 and the periods in which such revenues are expected to be realized (in millions):
 
2020
 
2021
 
2022
 
2023
and Beyond
 
 Total
Floaters
$
720.5

 
$
126.8

 
$

 
$

 
$
847.3

Jackups
748.5

 
365.6

 
166.8

 
0.3

 
1,281.2

Other(1)
168.9

 
145.3

 
10.1

 

 
324.3

Total
$
1,637.9


$
637.7


$
176.9


$
0.3

 
$
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.

Our drilling contracts generally contain provisions permitting early termination of the contract (i) if the rig is lost or destroyed or (ii) 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.”

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, 2020. 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 unit. 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 flow from the 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

9



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 first party coverage to us for physical damage to, including total loss or constructive total loss of, our rigs, generally 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 decided not to purchase first party windstorm insurance for our rigs in the U.S. Gulf of Mexico. Accordingly, we have retained the risk for windstorm damage to our four jackups and eight floaters in the U.S. Gulf of Mexico.

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.

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. In most drilling contracts, we assume liability for third-party damages resulting from such pollution and contamination caused by our negligence, usually subject to negotiated caps on a per occurrence or per event basis. In addition, in substantially all of our contracts, the customer assumes responsibility and indemnifies us for loss or damage to the reservoir, for loss of hydrocarbons escaping from the reservoir and for the costs of bringing the well under control.  Further, subject to the exceptions noted below, most of our contracts provide that the customer assumes responsibility and indemnifies us for loss or damage to the well, except when the loss or damage to the well is due to our negligence, in which case most of our contracts provide that the customer's sole remedy is to require us to redrill the lost or damaged portion of the well at a substantially reduced rate and, in some cases, pay for some of the costs to repair the well.

Most of our drilling contracts incorporate a broad exclusion that limits the operator's indemnity for damages and losses resulting from our gross negligence and willful misconduct and for fines and penalties and punitive damages levied or assessed directly against us. This exclusion overrides other provisions in the contract that would otherwise limit our liability for ordinary negligence. In most of these cases, we are still able to negotiate a liability cap (although these caps are significantly higher than the caps, we are able to negotiate for ordinary negligence) on our exposure for losses or damages resulting from our gross negligence. In certain cases, the broad exclusion only applies to losses or damages resulting from the gross negligence of our senior supervisory personnel. However, in some cases we have contractually assumed significantly increased exposure or unlimited exposure for losses and damages due to the gross negligence of some or all our personnel, and in most cases, we are not able to contractually limit our exposure for our willful misconduct.

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. 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.

10



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. In such cases, the contractual indemnity obligation of the operator to us would be enforceable with respect to third-party claims for losses of damages, such as may arise in pollution claims, but the contractual indemnity obligation of the operator to us with respect to injury or death to the operator's personnel and the operator’s damages to the well, to the reservoir and for the costs of well control would not be enforceable. 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.

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. In addition, our drilling contracts are individually negotiated, and the degree of indemnification we receive from operators against the liabilities discussed above can vary from contract to contract, based on market conditions and customer requirements existing when the contract was negotiated and the interpretation and enforcement of applicable law when the claim is adjudicated. Notwithstanding a contractual indemnity from a customer, there can be no assurance that our customers will be financially able to indemnify us or will otherwise honor a contractual indemnity obligation that is enforceable under applicable law. Our insurance program and the terms of our drilling contracts may change in the future.

In certain cases, vendors who provide equipment or services to us limit their pollution liability to a specific monetary cap, and we assume the liability above that cap. Typically, in the case of original equipment manufacturers, the cap is a negotiated amount based on mutual agreement of the parties considering the risk profiles and thresholds of each party. However, for smaller vendors, the liability is usually limited to the value, or double the value, of the contract.

We generally indemnify the customer for legal and financial consequences of spills of waste oil, fuels, lubricants, motor oils, pipe dope, paint, solvents, ballast, bilge, garbage, debris, sewage, hazardous waste and other liquids, the discharge of which originates from our rigs or equipment above the surface of the water and in some cases from our subsea equipment. Our contracts generally provide that, in the event of any such spill from our rigs, we are responsible for fines and penalties.

Major Customers

We provide our contract drilling services to major international, government-owned and independent oil and gas companies. During 2019, our five largest customers accounted for 44% of consolidated revenues. Total, our only customer who accounts for 10% or more of consolidated revenues, accounted for 16% of consolidated revenues.

Competition

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

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Governmental Regulation and Environmental Matters

Our operations are affected by political initiatives and by laws and regulations that relate to the oil and gas industry, including laws and regulations that have or may impose increased financial responsibility and oil spill abatement contingency plan capability requirements. Accordingly, we will be directly affected by the approval and adoption of laws and regulations curtailing exploration and development drilling for oil and natural gas for economic, environmental, safety or other policy reasons. It is also possible that these laws and regulations and political initiatives could adversely affect our operations in the future by significantly increasing our operating costs or restricting areas open for drilling activity.  See "Item 1A. Risk Factors- Increasing regulatory complexity could adversely impact the costs associated with our offshore drilling operations."

Our operations are subject to laws and regulations controlling the discharge of materials into the environment, pollution, contamination and hazardous waste disposal or otherwise relating to the protection of the environment. These laws and regulations may, among other things:

require the acquisition of various permits before drilling commences;

require notice to stakeholders of proposed and ongoing operations;

require the installation of expensive pollution control equipment;

restrict the types, quantities and concentration of various substances that can be released into the environment in connection with drilling; and

restrict the production rate of natural resources below the rate that would otherwise be possible.

Environmental laws and regulations specifically applicable to our business activities could impose significant liability on us for damages, clean-up costs, fines and penalties in the event of oil spills or similar discharges of pollutants or contaminants into the environment or improper disposal of hazardous waste generated in the course of our operations, which may not be covered by contractual indemnification or insurance or for which indemnity is prohibited by applicable law and could have a material adverse effect on our financial position, operating results and cash flows.  To date, such laws and regulations have not had a material adverse effect on our operating results.  However, the legislative, judicial and regulatory response to any well-control incidents could substantially increase our customers' liabilities in respect of oil spills and also could increase our liabilities. 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.

The International Convention on Oil Pollution Preparedness, Response and Cooperation, the International Convention on Civil Liability for Oil Pollution Damage 1992, the U.K. Merchant Shipping Act 1995, Marpol 73/78 (the International Convention for the Prevention of Pollution from Ships), the U.K. Merchant Shipping (Oil Pollution Preparedness, Response and Co-operation Convention) Regulations 1998, as amended, and other related legislation and regulations and the Oil Pollution Act of 1990 ("OPA 90"), as amended, the Clean Water Act and other U.S. federal statutes applicable to us and our operations, as well as similar statutes in Texas, Louisiana, other coastal states and other non-U.S. jurisdictions, address oil spill prevention, reporting and control and have significantly expanded potential liability, fine and penalty exposure across many segments of the oil and gas industry. 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. Similar environmental laws apply in our other areas of operation. Failure to comply with these statutes and regulations may subject us to civil or criminal enforcement action, which may not be covered by contractual indemnification or insurance,

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or for which indemnity is prohibited under applicable law, and could have a material adverse effect on our financial position, operating results and cash flows.

High-profile and catastrophic events such as the 2010 Macondo well incident have heightened governmental and environmental concerns about the oil and gas industry. From time to time, legislative proposals have been introduced that would materially limit or prohibit offshore drilling in certain areas.  We are adversely affected by restrictions on drilling in certain areas of the U.S. Gulf of Mexico and elsewhere, including the adoption of additional safety requirements and policies regarding the approval of drilling permits and restrictions on development and production activities in the U.S. Gulf of Mexico that have and may further impact our operations. 

As a result of Macondo, the 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. 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. Following federal court decisions successfully challenging the scope of BSEE’s jurisdiction over offshore contractors, this IPD has been removed from the list of IPDs on the BSEE website. 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 mobile offshore drilling units ("MODUs") and jackup 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.  On July 12, 2017, the USCG announced the availability of and requested comments on draft guidelines for addressing cyber risks at MTSA-regulated facilities.

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. 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. Specifically, the 2019 Well Control Rule addresses six areas of offshore operations: well design, well control, casing, cementing, real-time monitoring and subsea containment. The revisions were targeted to ensure safety and environmental protection while correcting errors in the 2016 rule and reducing unnecessary regulatory burden. Based on our current assessment of the rules, we do not expect to incur significant costs to comply with the 2016 Well Control Rule or 2019 Well Control Rule.
 
The continuing and evolving threat of cyber attacks will likely require increased expenditures to strengthen cyber risk management systems for MODUs and onshore facilities. For example, on May 11, 2017, President Trump issued EO 13800, 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 MODUs, 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.

Additionally, climate change is receiving increasing attention from scientists and legislators, and significant focus is being put on companies that are active producers of depleting natural resources. Globally, there are a number of legislative and regulatory proposals at various levels of government to address the greenhouse gas emissions that contribute to climate change. Although it is not possible at this time to predict how legislation or new regulations that may be adopted to address greenhouse gas emissions would impact our business, any such future laws and regulations could require us or our customers to incur increased operating costs. Any such legislation or regulatory programs

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could also increase the cost of consuming oil, and thereby reduce demand for oil, which could reduce our customers’ demand for our services. Consequently, legislation and regulatory programs to reduce greenhouse gas emissions could have an adverse effect on our financial position, operating results and cash flows.
    
If new laws are enacted or other government actions are taken that restrict or prohibit offshore drilling in our principal areas of operation or 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, our financial position, operating results and cash flows could be materially adversely affected.  See "Item 1A. Risk Factors - Compliance with or breach of environmental laws can be costly and could limit our operations." 

Non-U.S. Operations

Revenues from non-U.S. operations were 85%, 87% and 92% of our total consolidated revenues during 2019, 2018 and 2017, respectively. Our non-U.S. 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,


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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.

See "Item 1A. Risk Factors - Our non-U.S. operations involve additional risks not associated with U.S. operations."
Executive Officers
Officers generally serve for a one-year term or until successors are elected and qualified to serve. The table below sets forth certain information regarding our executive officers as of February 17, 2020:
Name
 
Age
 
Position         
Dr. Thomas Burke
 
52
 
President and Chief Executive Officer
Jonathan Baksht
 
45
 
Executive Vice President and Chief Financial Officer
Gilles Luca
 
48
 
Senior Vice President - Chief Operating Officer
Alan Quintero
 
56
 
Senior Vice President - Business Development
Michael T. McGuinty
 
57
 
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:

    Dr. 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. Dr. 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, Dr. 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. He serves on the executive committee of the International Association of Drilling Contractors. Dr. 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 - 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, 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. Mr. 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.

Gilles Luca joined Valaris in 1997 and was appointed to his current position of Senior Vice President - Chief Operating Officer in November 2019. Prior to his current position, Mr. Luca served as Senior Vice President - Western Hemisphere, Vice President - Business Development and Strategic Planning, Vice President - Brazil Business Unit and General Manager - Europe and Africa. He holds a Master's Degree in Petroleum Engineering from the French Petroleum Institute and a Bachelor in Civil Engineering from ESTP, Paris.


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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. Mr. 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.

Michael T. 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. Mr. 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.

Employees

Excluding contract employees, we employed approximately 5,800 personnel worldwide as of December 31, 2019.  The majority of our personnel work on rig crews and are compensated on an hourly basis.

Available Information

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to these reports that we file or furnish to the Securities and Exchange Commission ("SEC") in accordance with the Exchange Act are available on our website at www.valaris.com/investors. In addition, the SEC maintains an Internet site at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC. These reports also are available in print without charge by contacting our Investor Relations Department at 713-430-4607 as soon as reasonably practicable after we electronically file the information with, or furnish it to, the SEC.  The information contained on our website is not included as part of, or incorporated by reference into, this report.

Item 1A.  Risk Factors
 
Risks Related to Our Business
 
There are numerous factors that affect our business and operating results, many of which are beyond our control. The following is a description of significant factors that might cause our future operating results to differ materially from those currently expected. The risks described below are not the only risks facing our Company. 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.

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.

The success of our business largely depends on the level of activity in offshore oil and natural gas exploration, development and production. Oil and natural gas prices, and market expectations of potential changes in these prices, significantly affect the level of drilling activity. Historically, when drilling activity and operator capital spending decline, utilization and day rates also decline and drilling may be reduced or discontinued, resulting in an oversupply of drilling rigs. The oversupply of drilling rigs will be exacerbated by the entry of newbuild rigs into the market. Oil and natural gas prices have historically been volatile, and have declined significantly from prices in excess of $100

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since mid-2014 causing operators to reduce capital spending and cancel or defer existing programs, substantially reducing the opportunities for new drilling contracts. More recently, oil prices have increased meaningfully from the decade lows reached during 2016, with Brent crude averaging nearly $55 per barrel in 2017 and more than $70 per barrel through most of 2018, leading to signs of a gradual recovery in demand for offshore drilling services. However, macroeconomic and geopolitical headwinds triggered a decline in Brent crude prices in the fourth quarter of 2018, resulting in a decline in prices from more than $85 per barrel to approximately $50 per barrel at year-end. Oil prices have experienced a gradual recovery from this decline in 2019 with Brent crude prices averaging approximately $64 per barrel. Commodity prices have not improved to a level that supports increased rig demand sufficient to absorb existing rig supply and generate meaningful increases in day rates. We expect these trends to continue as long as commodity prices and rig supply remain at current levels. The lack of a meaningful recovery of oil and natural gas prices or further price reductions or volatility in prices may cause our customers to maintain historically low levels or further reduce their overall level of activity, in which case demand for our services may further decline and revenues may continue to be adversely affected through lower rig utilization and/or lower day rates.  Numerous factors may affect oil and natural gas prices and the level of demand for our services, including:

regional and global economic conditions and changes therein,

oil and natural gas supply and demand,

expectations regarding future energy prices, 

the ability of the Organization of Petroleum Exporting Countries ("OPEC") to reach further agreements to set and maintain production levels and pricing and to implement existing and future agreements, 

capital allocation decisions by our customers, including the relative economics of offshore development versus onshore prospects,

the level of production by non-OPEC countries, 

U.S. and non-U.S. tax policy, 

advances in exploration and development technology,

costs associated with exploring for, developing, producing and delivering oil and natural gas, 

the rate of discovery of new oil and gas reserves and the rate of decline of existing oil and gas reserves, 

laws and government regulations that limit, restrict or prohibit exploration and development of oil and natural gas in various jurisdictions, or materially increase the cost of such exploration and development,

the development and exploitation of alternative fuels or energy sources and increased demand for electric-powered vehicles, 

disruption to exploration and development activities due to hurricanes and other severe weather conditions and the risk thereof, 

natural disasters or incidents resulting from operating hazards inherent in offshore drilling, such as oil spills,

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

the worldwide military or political environment, including the global macroeconomic effects of trade disputes and increased tariffs and sanctions and uncertainty or instability resulting from an escalation or additional outbreak of armed hostilities or other crises in oil or natural gas producing areas of the Middle East or geographic areas in which we operate, or acts of terrorism.

Despite significant declines in capital spending and cancelled or deferred drilling programs by many operators since 2014, oil and gas production has not yet been reduced by amounts sufficient to result in a rebound in pricing to levels seen prior to the current downturn, and we may not see sufficient supply reductions or a resulting rebound in

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pricing for an extended period of time. Further, the agreements of OPEC and certain non-OPEC countries to freeze and/or cut production may not be fully realized. The lack of actual production cuts or freezes, or the perceived risk that OPEC countries may not comply with such agreements, may result in depressed commodity prices for an extended period of time.

Higher commodity prices may not necessarily translate into increased activity, and even during periods of high commodity prices, customers may cancel or curtail their drilling programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons, including their lack of success in exploration efforts. Advances in onshore exploration and development technologies, particularly with respect to onshore shale, could also result in our customers allocating more of their capital expenditure budgets to onshore exploration and production activities and less to offshore activities. These factors could cause our revenues and profits to decline further, as a result of declines in utilization and day rates, and limit our future growth prospects. Any significant decline in day rates or utilization of our rigs, particularly our high-specification floaters, could materially reduce our revenues and profitability. In addition, these risks could increase instability in the financial and insurance markets and make it more difficult for us to access capital and obtain insurance coverage that we consider adequate or are otherwise required by our contracts.

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 industry is highly competitive, and our contracts are traditionally awarded on a competitive bid basis. Pricing, safety records and competency are key factors in determining which qualified contractor is awarded a job. Rig availability, location and technical capabilities also can be significant factors in the determination. If we are not able to compete successfully, our revenues and profitability may be reduced.

The offshore contract drilling industry historically has been very cyclical and is primarily related to the demand for drilling rigs and the available supply of drilling rigs.  Demand for rigs is directly related to the regional and worldwide levels of offshore exploration and development spending by oil and gas companies, which is beyond our control. Offshore exploration and development spending may fluctuate substantially from year-to-year and from region-to-region.

The significant decline in oil and gas prices and resulting reduction in spending by our customers, together with the increase in supply of offshore drilling rigs in recent years, has resulted in an oversupply of offshore drilling rigs and a decline in utilization and day rates, a situation which may persist for many years.

Such a prolonged period of reduced demand and/or excess rig supply has required us, and may in the future require us, to idle or scrap rigs and enter into low day rate contracts or contracts with unfavorable terms. There can be no assurance that the current demand for drilling rigs will increase in the future. Any further decline in demand for drilling rigs or a continued oversupply of drilling rigs could adversely affect our financial position, operating results or cash flows.

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

Our ability to renew expiring contracts or obtain new contracts and the terms of any such contracts will depend on market conditions. Our customers’ decisions to exercise options resulting in additional work for the rig under contract also depend on market conditions. We may be unable to renew our expiring contracts, including contracts expiring for failure by the customer to exercise option periods, or obtain new contracts for the rigs under contracts that have expired or have been terminated, and the day rates under any new contracts or any renegotiated contracts may be substantially below the existing day rates, which could adversely affect our revenues and profitability. In addition, if customers do not exercise option periods under contracts that we currently expect to be exercised, we may face longer downtime associated with the related rig, as we would have difficulty tendering that rig for additional work to cover the option period.


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Our two rigs under construction, which are scheduled for delivery between 2021 and 2022, are currently uncontracted. There is no assurance that we will secure drilling contracts for these rigs, or future rigs we construct or acquire, or that the drilling contracts we may be able to secure will be based upon rates and terms that will provide a reasonable rate of return on these investments. Our failure to secure contracts for these rigs at day rates and terms that result in a reasonable return upon completion of construction may result in a material adverse effect on our financial position, operating results or cash flows.

We have a significant amount of debt. Our debt levels and debt agreement restrictions may limit our liquidity and flexibility in refinancing our debt, obtaining additional financing and pursuing other business opportunities.
 
As of December 31, 2019, we had $6.5 billion in total debt outstanding, representing approximately 41.2% of our total capitalization, including 6.785% senior notes due 2020 with an aggregate outstanding principal balance of $122.9 million. As of December 31, 2019, $2.6 billion outstanding principal amount of our debt had a maturity date prior to year-end 2024. Our current indebtedness may have several important effects on our future operations, including:
 
a substantial portion of our cash flows from operations will be dedicated to the payment of principal and interest,
 
covenants contained in our debt arrangements require us to meet certain financial tests, which may affect our flexibility in planning for, and reacting to, changes in our business and may limit our ability to dispose of assets or place restrictions on the use of proceeds from such dispositions, withstand current or future economic or industry downturns and compete with others in our industry for strategic opportunities, and 

our ability to access capital markets, refinance our existing indebtedness, raise capital on favorable terms, or obtain additional financing to fund working capital requirements, capital expenditures, acquisitions, debt service requirements, execution of our business strategy and general corporate or other cash requirements may be limited.

Our ability to maintain a sufficient level of liquidity to meet our financial obligations will be dependent upon our future performance, which will be subject to general economic conditions, industry cycles and financial, business and other factors affecting our operations, many of which are beyond our control. For 2019 and 2018, our cash flows from operating activities of continuing operations were negative $276.9 million and $55.7 million, respectively, and we further incurred capital expenditures on continuing operations of $227.0 million and $426.7 million, respectively. Our operating activities and capital expenditures are expected to continue to result in significant negative annual cash flow in 2020. Meaningful recovery in drilling demand and day rates are required for annual cash flow to turn positive in 2021 and beyond. We cannot be certain that our future cash flows will be sufficient to meet all of our debt obligations, working capital requirements and contractual commitments. Any cash flow insufficiency would have a material adverse impact on our business, financial condition, results of operations, cash flows and liquidity and our ability to repay or refinance our debt.
 
To the extent we are unable to repay our debt and other obligations as they become due with cash on hand or from other sources, we will need to restructure or refinance all or part of our debt, sell assets, reduce capital expenditures, borrow more cash or raise equity. Additional indebtedness or equity financing may not be available to us in the future for the refinancing or repayment of existing debt and other obligations, or if available, such additional debt or equity financing may not be available in a sufficient amount, on a timely basis, or on terms acceptable to us and within the limitations specified in our then existing debt instruments. In addition, in the event we decide to sell additional assets, we can provide no assurance as to the timing of any asset sales or the proceeds that could be realized by us from any such asset sale. In addition, we may pursue various liability management transactions to extend our debt maturities and reduce the outstanding principal amount of our debt. These liability management efforts may be unsuccessful or may not improve our financial position to the extent anticipated.

Our revolving credit facility places restrictions on us and certain of our subsidiaries with respect to incurring additional indebtedness and liens, paying dividends and other payments to shareholders, repurchasing our ordinary

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shares, repurchasing or redeeming certain other indebtedness which matures after the revolving credit facility, entering into mergers and other matters. Our revolving credit facility also requires compliance with covenants to maintain specified financial and guarantee coverage ratios, including a total debt to total capitalization ratio that is less than or equal to 60%. As of December 31, 2019, such ratio was 41.2%. If we incur material impairments in future periods, we may not be able to comply with such financial covenant. In addition, these restrictions may limit our flexibility in obtaining additional financing and in pursuing various business opportunities.

Further, if for any reason we are unable to meet our debt service and repayment obligations or to comply with the payment, financial and other covenants in the agreements governing our debt, we would be in default under the terms of such agreements, which could allow our creditors under those agreements to declare all outstanding indebtedness thereunder to be due and payable (which would in turn trigger cross-acceleration or cross-default rights between the relevant agreements), the lenders under our credit facilities could terminate their commitments to extend credit, and we could be forced into bankruptcy or liquidation. If the amounts outstanding under our credit facility or any of our other significant indebtedness were to be accelerated, we cannot assure you that our assets would be sufficient to repay in full the amounts owed to the lenders or to our other debt holders.

In addition, our access to credit and capital markets, in part, depends on the credit ratings assigned to our credit facility and our notes by independent credit rating agencies. In recent years, we have experienced significant downgrades in our corporate credit rating and the credit rating of our senior notes. Our access to credit and capital markets is more limited due to these downgrades and the associated weakening of our credit metrics. Any additional actual or anticipated downgrades in our corporate credit rating or the credit rating of our notes will further limit our ability to access credit and capital markets, or to restructure or refinance our indebtedness. Furthermore, future financings or refinancings may result in higher borrowing costs, require collateral, or contain more restrictive terms and covenants, which will further restrict our operations. With our current credit ratings, we have no access to the commercial paper market. Limitations on our ability to access credit and capital markets could have a material adverse impact on our financial position, operating results or cash flows.

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 resulting from operations under the contract.

Certain of our customers are subject to liquidity risk and such risk could lead them to seek to repudiate, cancel or renegotiate our drilling contracts or fail to fulfill their commitments to us under those contracts. These risks are heightened in periods of depressed market conditions. Our drilling contracts provide for varying levels of indemnification from our customers, including with respect to well-control, reservoir liability and pollution. Our drilling contracts also provide for varying levels of indemnification and allocation of liabilities between our customers and us with respect to loss or damage to property and injury or death to persons arising from the drilling operations we perform. Under our drilling contracts, liability with respect to personnel and property customarily is allocated so that we and our customers each assume liability for our respective personnel and property. Our customers have historically assumed most of the responsibility for and indemnified us from any loss, damage or other liability resulting from pollution or contamination, including clean-up and removal and third-party damages arising from operations under the contract when the source of the pollution originates from the well or reservoir, including those resulting from blow-outs or cratering of the well. However, we regularly are required to assume a limited amount of liability for pollution damage caused by our negligence, which liability generally has caps for ordinary negligence, with much higher caps or unlimited liability where the damage is caused by our gross negligence. Notwithstanding a contractual indemnity from a customer, there can be no assurance that our customers will be financially able to assume their responsibility and honor their indemnity to us for such losses. In addition, under the laws of certain jurisdictions, such indemnities under certain circumstances are not enforceable if the cause of the damage was our gross negligence or willful misconduct. This could result in us having to assume liabilities in excess of those agreed in our contracts due to customer balance sheet or liquidity issues or applicable law.


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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.

In market downturns similar to the current environment, our customers may not be able to honor the terms of existing contracts, may terminate contracts even where there may be onerous termination fees, may seek to void or otherwise repudiate our contracts including by claiming we have breached the contract, or may seek to renegotiate contract day rates and terms in light of depressed market conditions. Since early 2015, we have renegotiated a number of contracts and received termination notices with respect to several of our rigs. Often, our drilling contracts are subject to termination without cause or termination for convenience upon notice by the customer. In certain cases, our contracts require the customer to pay an early termination fee in the event of a termination for convenience (without cause). Such payment would provide some level of compensation to us for the lost revenue from the contract but in many cases would not fully compensate us for all of the lost revenue. Certain of our contracts permit termination by the customer without an early termination fee. Furthermore, financially distressed customers may seek to negotiate reduced termination fees as part of a restructuring package.

Drilling contracts customarily specify automatic termination or termination at the option of the customer in the event of a total loss of the drilling rig and often include provisions addressing termination rights or reduction or cessation of day rates if operations are suspended or interrupted for extended periods due to breakdown of major rig equipment, unsatisfactory performance, "force majeure" events beyond the control of either party or other specified conditions.

If a customer cancels a contract or if we terminate a contract due to the customer’s breach and, in either case, we are unable to secure a new contract on a timely basis and on substantially similar terms, or if a contract is disputed or suspended for an extended period of time or renegotiated, it could materially and adversely affect our financial position, operating results or cash flows.

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

We evaluate the carrying value of our property and equipment, primarily our drilling rigs, when events or changes in circumstances indicate that the carrying value of such rigs may not be recoverable. The offshore drilling industry historically has been highly cyclical, and it is not unusual for rigs to be idle or underutilized for significant periods of time and subsequently resume full or near full utilization when business cycles change. Likewise, during periods in which rig supply exceeds rig demand, competition may force us to contract our rigs at or near cash break-even rates for extended periods of time.

Since 2014 we have recorded pre-tax, non-cash losses on impairment of long-lived assets totaling $5.4 billion. Further asset impairments may be necessary if market conditions remain depressed for longer than we expect. See Note 6 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information.

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

We provide our services to major international, government-owned and independent oil and gas companies.  During 2019, our five largest customers accounted for 44% of our consolidated revenues in the aggregate, with our largest customer representing 16% of our consolidated revenues and a significant percentage of our operating cash flows.  Certain of our largest customers have discussed with us our financial viability to perform for the duration of the potential terms of new contracts. Our financial position, operating results or cash flows may be materially adversely affected if any of our higher day rate contracts were terminated or renegotiated on less favorable terms or if a major customer terminates its contracts with us, fails to renew its existing contracts with us, requires renegotiation of our contracts or declines to award new contracts to us.


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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, operating results or cash flows.

As of December 31, 2019, our contract backlog was approximately $2.5 billion, which represents an increase of $270.4 million to the reported backlog of $2.2 billion as of December 31, 2018. This amount reflects the remaining contractual terms multiplied by the applicable contractual day rate. The contractual revenue may be higher than the actual revenue we ultimately receive because of a number of factors, including rig downtime or suspension of operations. Several factors could cause rig downtime or a suspension of operations, many of which are beyond our control, including:

the early termination, repudiation or renegotiation of contracts,

breakdowns of equipment,

work stoppages, including labor strikes,

shortages of material or skilled labor,

surveys by government and maritime authorities,

periodic classification surveys,

severe weather, strong ocean currents or harsh operating conditions,

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

force majeure events.

Our customers may seek to terminate, repudiate or renegotiate our drilling contracts for various reasons. Generally, our drilling contracts permit early termination of the contract by the customer for convenience (without cause), exercisable upon advance notice to us, and in certain 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 decline in oil prices and the resulting downward pressure on utilization has caused and may continue to cause some customers to consider early termination of select contracts despite having to pay onerous early termination fees in certain cases. Customers may continue to request to renegotiate the terms of existing contracts, or they may request early termination or seek to repudiate contracts in some circumstances. Furthermore, as our existing contracts expire, we may be unable to secure new contracts for our rigs. Therefore, revenues recorded in future periods could differ materially from our current backlog. Our inability to realize the full amount of our contract backlog may have a material adverse effect on our financial position, operating results or cash flows.

We may not realize the expected benefits of the ARO joint venture and it may introduce additional risks to our business.

In November 2016, Rowan and Saudi Aramco announced plans to form a 50/50 joint venture with Rowan and Saudi Aramco each selling existing drilling units and contributing capital as the foundation of the new company. The new entity, ARO, commenced operations on October 17, 2017, and is expected to add up to 20 newbuild jackup rigs to its fleet over an approximate 10 year period. In January 2020, ARO ordered the first two newbuild jackups for delivery scheduled in 2022. There can be no assurance that the new jackup rigs will begin operations as anticipated or we will realize the expected return on our investment. We may also experience difficulty jointly managing the venture, and integrating our existing employees, business systems, technologies and services with those of Saudi Aramco in order to operate the joint venture efficiently. Further, in the event ARO has insufficient cash from operations or is unable to obtain third party financing, we may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion. Any required capital contributions we make will

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negatively impact our liquidity position and financial condition. As a result of these risks, it may take longer than expected for us to realize the expected returns from ARO or such returns may ultimately be less than anticipated. Additionally, if we are unable to make any required contributions, our ownership in ARO could be diluted which could hinder our ability to effectively manage ARO and adversely impact our operating results or financial condition.

ARO, as a provider of offshore drilling services, faces many of the same risks as we face. Operating through ARO, in which we have a shared interest, may result in our having less control over many decisions made with respect to projects, operations, safety, utilization, internal controls and other operating and financial matters. ARO may not apply the same controls and policies that we follow to manage our risks, and ARO’s controls and policies may not be as effective. As a result, operational, financial and control issues may arise, which could have a material adverse effect on our financial condition and results of operations. Additionally, in order to establish or preserve our relationship with our joint venture partner, we may agree to risks and contributions of resources that are proportionately greater than the returns we could receive, which could reduce our income and return on our investment in ARO compared to what we may traditionally require in other areas of our business.

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

We have announced that we are targeting significant synergies and cost savings in connection with the Rowan Transaction. We also have announced that we are implementing additional initiatives targeting significant additional operating cost savings. As we implement these synergy and cost-saving initiatives, we may not realize anticipated savings or other benefits from one or more of the initiatives in the amounts or within the time periods we expect. The cost-reduction actions could negatively impact or disrupt our operations. The impact of these cost-reduction actions on our operations may be influenced by many factors, including declines in employee morale and the potential inability to meet operational targets due to our inability to retain or recruit key employees. Additionally, the cost-reductions actions could lead to the deterioration or failure of our operational and financial controls due to an inability to properly control and manage change, employee attrition, financial and operation system conversion and other factors that could adversely impact our business during the implementation or respective cost-reduction initiatives. If we experience any of these circumstances or otherwise fail to realize the anticipated savings or benefits from our synergy and cost-saving initiatives, our financial condition, results of operations and cash flows could be materially and adversely affected.

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.

Our operations are subject to hazards inherent in the offshore drilling industry, such as blow-outs, reservoir damage, loss of production, loss of well-control, uncontrolled formation pressures, lost or stuck drill strings, equipment failures and mechanical breakdowns, punchthroughs, craterings, industrial accidents, fires, explosions, oil spills and pollution. These hazards can cause personal injury or loss of life, severe damage to or destruction of property and equipment, pollution or environmental damage, which could lead to claims by third parties or customers, suspension of operations and contract terminations. Our fleet is also subject to hazards inherent in marine operations, either while on-site or during mobilization, such as punch-throughs, capsizing, sinking, grounding, collision, damage from severe weather and marine life infestations.  Additionally, a cyber attack or other security breach of our information systems or other technological failure could lead to a material disruption of our operations, information systems and/or loss of business information, which could result in an adverse impact to our business.  Our drilling contracts provide for varying levels of indemnification from our customers, including with respect to well-control and subsurface risks. For example, most of our drilling contracts incorporate a broad exclusion that limits the customer's indemnity rights for damages and losses resulting from our gross negligence and willful misconduct and for fines and penalties and punitive damages levied or assessed directly against us. We also maintain insurance for personal injuries, damage to or loss of equipment and other insurance coverage for various business risks.

We generally identify the operational hazards for which we will procure insurance coverage based on the likelihood of loss, the potential magnitude of loss, the cost of coverage, the requirements of our customer contracts

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and applicable legal requirements. Although we maintain what we believe to be an appropriate level of insurance covering hazards and risks we currently encounter during our operations, no assurance can be given that we will be able to obtain insurance against all potential risks and hazards, or that we will be able to maintain the same levels and types of coverage that we have maintained in the past. Our financial leverage and negative cash flow could cause insurance companies to increase our premiums and deductibles or limit our coverage amounts.

As a result of climate change activism or increased costs to insurance companies due to regulatory, geopolitical or other developments, insurance companies that have historically participated in underwriting energy-related risks may discontinue that practice, may reduce the insurance capacity they are willing to offer or demand significantly higher premiums or deductible periods to cover these risks.

Furthermore, our insurance carriers may interpret our insurance policies such that they do not cover losses for all of our claims. Our insurance policies may also have exclusions of coverage for some losses. Uninsured exposures may include radiation hazards, certain loss or damage to property onboard our rigs and losses relating to shore-based terrorist acts or strikes.

If we are unable to obtain or maintain adequate insurance at rates and with deductibles or retention amounts that we consider commercially reasonable, we may choose to forgo insurance coverage and retain the associated risk of loss or damage.

If a significant accident or other event occurs and is not fully covered by insurance or contractual indemnity (or if our contractual indemnity is not enforceable under applicable law or our clients are unable to meet their indemnification obligation), it could adversely affect our financial position, operating results or cash flows.

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, which could adversely affect our business.

Certain areas in and near the U.S. Gulf of Mexico experience hurricanes and other extreme weather conditions on a relatively frequent basis. Some of our drilling rigs in the U.S. Gulf of Mexico are located in areas that could cause them to be susceptible to damage and/or total loss by these storms, and we have a larger concentration of jackup rigs in the U.S. Gulf of Mexico than most of our competitors. We currently have four jackup rigs and eight floaters in the U.S. Gulf of Mexico. Damage caused by high winds and turbulent seas could result in rig loss or damage, termination of drilling contracts for lost or severely damaged rigs or curtailment of operations on damaged drilling rigs with reduced or suspended day rates for significant periods of time until the damage can be repaired. Moreover, even if our drilling rigs are not directly damaged by such storms, we may experience disruptions in our operations due to damage to our customers' platforms and other related facilities in the area. Our drilling operations in the U.S. Gulf of Mexico have been impacted by hurricanes in the past, including the total loss of drilling rigs, with associated losses of contract revenues and potential liabilities.

Insurance companies incurred substantial losses in the offshore drilling, exploration and production industries as a consequence of hurricanes that occurred in the U.S. Gulf of Mexico during 2004, 2005 and 2008. Accordingly, insurance companies have substantially reduced the nature and amount of insurance coverage available for losses arising from named tropical storm or hurricane damage in the U.S. Gulf of Mexico and have dramatically increased the cost of available windstorm coverage. The tight insurance market not only applies to coverage related to U.S. Gulf of Mexico windstorm damage or loss of our drilling rigs, but also impacts coverage for any potential liabilities to third parties associated with property damage, personal injury or death and environmental liabilities, as well as coverage for removal of wreckage and debris associated with hurricane losses. It is likely that the tight insurance market for windstorm damage, liabilities and removal of wreckage and debris will continue into the foreseeable future.

We do not purchase windstorm insurance for hull and machinery losses to our floaters arising from windstorm damage in the U.S. Gulf of Mexico due to the significant premium, high deductible and limited coverage for windstorm damage. We opted out of windstorm insurance for our jackups in the U.S. Gulf of Mexico during 2009 and have not

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since renewed that insurance. We believe it is no longer customary for drilling contractors with similar size and fleet composition to purchase windstorm insurance for rigs in the U.S. Gulf of Mexico for the aforementioned reasons. Accordingly, we have retained the risk of loss or damage for our four jackups and eight floaters arising from windstorm damage in the U.S. Gulf of Mexico.

We have established operational procedures designed to mitigate risk to our jackup rigs in the U.S. Gulf of Mexico during hurricane season, and these procedures may, on occasion, result in a decision to decline to operate on a customer-designated location during hurricane season notwithstanding that the location, water depth and other standard operating conditions are within a rig's normal operating range. Our procedures and the associated regulatory requirements addressing MODU operations in the U.S. Gulf of Mexico during hurricane season, coupled with our decision to retain (self-insure) certain windstorm-related risks, may result in a significant reduction in the utilization of our jackup rigs in the U.S. Gulf of Mexico.

Our annual insurance policies are up for renewal effective May 31, 2020, and any retained exposures for property loss or damage and wreckage and debris removal or other liabilities associated with U.S. Gulf of Mexico tropical storms or hurricanes may have a material adverse effect on our financial position, operating results or cash flows if we sustain significant uninsured or underinsured losses or liabilities as a result of these storms or hurricanes.

Our non-U.S. operations involve additional risks not typically associated with U.S. operations.

Revenues from non-U.S. operations were 85%, 87% and 92% of our total revenues during 2019, 2018 and 2017, respectively. Our non-U.S. 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, 


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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.

We historically have maintained insurance coverage and obtained contractual indemnities that protect us from some, but not all, of the risks associated with our non-U.S. operations such as nationalization, deprivation, expropriation, confiscation, political and war risks. However, there can be no assurance that any particular type of contractual or insurance protection will be available in the future or that we will be able to purchase our desired level of insurance coverage at commercially feasible rates.  Moreover, we may initiate a self-insurance program through one or more captive insurance subsidiaries.  In circumstances where we have insurance protection for some or all of the risks sometimes associated with non-U.S. operations, such insurance may be subject to cancellation on short notice, and it is unlikely that we would be able to remove our rig or rigs from the affected area within the notice period. Accordingly, a significant event for which we are uninsured, underinsured or self-insured, or for which we have not received an enforceable contractual indemnity from a customer, could cause a material adverse effect on our financial position, operating results or cash flows.

We are subject to various tax laws and regulations in substantially all countries in which we operate or have a legal presence. We evaluate applicable tax laws and employ various business structures and operating strategies to obtain the optimal level of taxation on our revenues, income, assets and personnel. Actions by tax authorities that impact our business structures and operating strategies, such as changes to tax treaties, laws and regulations, or the interpretation or repeal of any of the foregoing or changes in the administrative practices and precedents of tax authorities, adverse rulings in connection with audits or otherwise, or other challenges may substantially increase our tax expense.

As required by law, we file periodic tax returns that are subject to review and examination by various revenue agencies within the jurisdictions in which we operate. During 2019, we received income tax assessments totaling approximately €142.0 million (approximately $159.0 million converted using the current period-end exchange rates) and A$101 million (approximately $70.9 million converted at current period-end exchange rates) from taxing authorities in Luxembourg and Australia, respectively. See Note 12 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on income taxes.

During the third quarter of 2019, we made a A$42 million payment (approximately $29 million at then-current exchange rates) to the Australian tax authorities to litigate the assessment. We are also contesting the Luxembourg tax assessments. We may make a payment to the Luxembourg tax authorities in advance of the final resolution of these

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assessments. Although the outcome of such assessments cannot be predicted with certainty, unfavorable outcomes could have a material adverse effect on our liquidity.

Our non-U.S. operations also face the risk of fluctuating currency values, which may impact our revenues, operating costs and capital expenditures. We currently conduct contract drilling operations in certain countries that have experienced substantial fluctuations in the value of their currency compared to the U.S. dollar. In addition, some of the countries in which we operate have occasionally enacted exchange controls. Generally, we have contractually mitigated these risks by invoicing and receiving payment in U.S. dollars (our functional currency) or freely convertible currency and, to the extent possible, by limiting our acceptance of foreign currency to amounts which approximate our expenditure requirements in such currencies. However, not all of our contracts contain these terms and there is no assurance that our contracts will contain such terms in the future.

A portion of the costs and expenditures incurred by our non-U.S. operations, including certain capital expenditures, are settled in local currencies, exposing us to risks associated with fluctuation in the value of these currencies relative to the U.S. dollar. We use foreign currency forward contracts to reduce this exposure in certain cases. However, a relative weakening in the value of the U.S. dollar in relation to the local currencies in these countries may increase our costs and expenditures.

Our non-U.S. operations are also subject to various laws and regulations in countries in which we operate, including laws and regulations relating to the operation of drilling rigs and the requirements for equipment. We may be required to make significant capital expenditures to operate in such countries, which may not be reimbursed by our customers. Governments in some countries have become increasingly active in regulating and controlling the ownership of oil, natural gas and mineral concessions and companies holding concessions, the exploration of oil and natural gas and other aspects of the oil and gas industry in their countries. In some areas of the world, government activity has adversely affected the amount of exploration and development work performed by major international oil companies and may continue to do so. Moreover, certain countries accord preferential treatment to local contractors or joint ventures or impose specific quotas for local goods and services, which can increase our operational costs and place us at a competitive disadvantage. There can be no assurance that such laws and regulations or activities will not have a material adverse effect on our future operations.
    
The shipment of goods, services and technology across international borders subjects us to extensive trade laws and regulations. Our import activities are governed by specific customs laws and regulations in each of the countries where we operate. Moreover, many countries, including the United States, control the export and re-export of certain goods, services and technology and impose related export recordkeeping and reporting obligations. Governments also may impose express or de facto economic sanctions against certain countries, persons and other entities that may restrict or prohibit transactions involving such countries, persons and entities.

The laws and regulations concerning import activity, export recordkeeping and reporting, 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. Shipments can be delayed and denied export or entry 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, reduced day rates during such downtime and contract cancellations. Any failure to comply with applicable legal and regulatory trading obligations also could result in criminal and civil penalties and sanctions, such as fines, imprisonment, exclusion from government contracts, seizure of shipments and loss of import and export privileges.

Our employees, contractors and agents may take actions in violation of our policies and procedures designed to promote compliance with the laws of the jurisdictions in which we operate. Any such violation could have a material adverse effect on our financial position, operating results or cash flows.

We may not achieve the intended results from the Rowan Transaction, and we may not be able to successfully integrate our operations after the Rowan Transaction. Failure to successfully integrate Rowan may adversely affect our future results, and consequently, the value of our shares.

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We consummated the Rowan Transaction with the expectation that it would result in various benefits, including, among others, expanding our geographic presence and customer base and creating synergies, including $165 million of merger synergies and at least $100 million of other operating cost savings. We closed the Rowan Transaction on April 11, 2019; however, achieving the anticipated benefits of the Rowan Transaction is subject to a number of uncertainties, including whether the Rowan business can be integrated in an efficient and effective manner.

While we have successfully merged companies into our operations in the past, the integration process could take longer than anticipated and could result in the loss of valuable employees, the disruption of our ongoing business, processes and systems or inconsistencies in standards, controls, procedures, practices, policies and compensation arrangements, any of which could adversely affect our ability to achieve the anticipated benefits of the Rowan Transaction. Our combined operations could be adversely affected by issues attributable to Rowan’s historical operations that arose or are based on events or actions that occurred prior to the completion of the Rowan Transaction. In addition, integrating Rowan’s employees and operations will require the time and attention of management, which may negatively impact our business. Events outside of our control, including changes in regulation and laws, could adversely affect our ability to realize the expected benefits, including merger synergies and other cost savings, from the Rowan Transaction.

The results of the U.K.'s referendum on withdrawal from the E.U. may have a negative effect on economic conditions, financial markets and our business.
In June 2016, a referendum was held in the U.K. which resulted in a majority voting in favor of the U.K. withdrawing from the E.U. (commonly referred to as “Brexit”). Pursuant to legislation approved by the U.K. Parliament and the E.U. Parliament in January 2020, the U.K. withdrew from the E.U. with effect from 11 p.m. (GMT) on January 31, 2020 on the terms of a withdrawal agreement agreed between the U.K. and the E.U. in October 2019 (the “Withdrawal Agreement”). The Withdrawal Agreement provides that the U.K.’s withdrawal is followed by a “transition period”, during which, in summary, the U.K. is not a member of the E.U. but most E.U. rules and regulations continue to apply to the U.K. During the transition period, the U.K. and the E.U. will seek to negotiate the terms of a long-term trading relationship between the U.K. and the E.U. based on a “Political Declaration” agreed between the U.K. and the E.U. in October 2019. The transition period provided for in the Withdrawal Agreement will expire on December 31, 2020 (unless both the U.K. and the E.U. agree to extend the period of transition by one or two years).
The political negotiation surrounding the terms of the U.K.’s withdrawal from the E.U. has created significant uncertainty about the future relationship between the U.K. and the E.U., including with respect to the laws and regulations that will apply. This is because, once the “transition period” expires then, subject to the terms of any long-term trading relationship agreed between the U.K. and the E.U., the U.K. will determine which E.U.-derived laws to replace or replicate. The U.K.’s withdrawal from the E.U. has also given rise to calls for the governments of other E.U. member states to consider withdrawal, while the U.K.’s withdrawal negotiation process has increased the risk of the possibility of a further referendum concerning Scotland’s independence from the rest of the U.K.
If no long-term trading relationship is agreed between the U.K. and the E.U. by the end of the transition period provided for in the Withdrawal Agreement, the U.K.’s membership of the E.U. could ultimately terminate under a so-called “hard Brexit.” Under this scenario, there could be increased costs from the imposition of tariffs on trade or non-tariff barriers between the U.K. and E.U., shipping delays because of the need for customs inspections and temporary shortages of certain goods. Any of the foregoing might cause our U.K. suppliers to pass along these increased costs, if realized, to us in the U.K. In addition, trade and investment between the U.K., the E.U. and other countries would be impacted by the fact that the U.K. currently operates under tax and trade treaties concluded between the E.U. and other countries. Following a “hard Brexit”, the U.K. would need to negotiate its own tax and trade treaties with other countries, as well as with the E.U.. Any new, or changes to existing, U.K. tax laws could make the U.K. a less desirable jurisdiction of incorporation for our parent company, Valaris plc. In addition, one of our U.K. subsidiaries owns two jackup rigs, and following a “hard Brexit,” the E.U. might require some form of importation fee or guarantee on certain U.K. owned rigs that operate outside U.K. waters.
These developments, or the perception that any of them could occur, have had and may continue to have a material adverse effect on global, regional and/or national economic conditions and the stability of global financial

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markets, and may significantly reduce global market liquidity and restrict the ability of key market participants to operate in certain financial markets. Any of these factors could depress economic activity, result in changes to currency exchange rates, tariffs, treaties, taxes, import/export regulations, laws and other regulatory matters, and/or restrict our access to capital and the free movement of our employees, which could have a material adverse effect on our financial position, operating results or cash flows. Approximately 10% of our total revenues were generated in the U.K. for the year ended December 31, 2019.

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

We currently own and operate 13 rigs that are contracted with national oil companies. The terms of these contracts are often non-negotiable and may expose us to greater commercial, political and operational risks than we assume in other contracts, such as exposure to materially greater environmental liability, personal injury and other claims for damages (including consequential damages), or the risk that the contract may be terminated by our customer without cause on short-term notice, contractually or by governmental action, under certain conditions that may not provide us with an early termination payment. We can provide no assurance that the increased risk exposure will not have an adverse impact on our future operations or that we will not increase the number of rigs contracted to national oil companies with commensurate additional contractual risks.

We do not currently pay dividends and cannot assure you that we will pay dividends or otherwise return capital to shareholders in the future. Our indebtedness limits our ability to pay dividends and repurchase shares.

Our Board of Directors declared a $0.01 (pre-reverse stock split) quarterly cash dividend per Class A ordinary share for each quarter during 2017 and 2018 and the first quarter of 2019. In the second quarter of 2019, our Board of Directors determined that we will not pay a regular quarterly cash dividend. The declaration and amount of future dividends is at the discretion of our Board of Directors and will depend on our profitability, liquidity, financial condition, market outlook, reinvestment opportunities, capital requirements, restrictions and limitations in our credit facility and other debt documents and other factors and restrictions our Board of Directors deems relevant. Our revolving credit facility restricts payment of dividends in excess of a regular quarterly dividend of $0.01 per share and prohibits the repurchase of shares, except in certain limited circumstances. Future agreements may have similar restrictions. There can be no assurance that we will pay a dividend or otherwise return capital to shareholders in the future.

Legal and regulatory proceedings could adversely affect us.

We are involved in litigation, including various claims, disputes and regulatory proceedings that arise in the ordinary course of business, many of which are uninsured and relate to intellectual property, commercial, operational, employment, regulatory or other activities.

We operate in a number of countries throughout the world, including countries known to have a reputation for corruption and are subject to the U.S. Foreign Corrupt Practices Act of 1977 (“FCPA”), the U.S. Treasury Department's Office of Foreign Assets Control ("OFAC") regulations, the U.K. Bribery Act ("UKBA"), other U.S. laws and regulations governing our international operations and similar laws in other countries.

In August 2017, one of our Brazilian subsidiaries was contacted by the Office of the Attorney General for the Brazilian state of Paraná in connection with a criminal investigation procedure initiated against agents of both Samsung Heavy Industries, a shipyard in South Korea (“SHI”), and Pride International LLC ("Pride") in relation to the drilling services agreement with Petrobras for the DS-5 (the "DSA"). The Brazilian authorities requested information regarding our compliance program and the findings of our internal investigations relating to the DSA. We cooperated with the Office of the Attorney General and provided documents in response to its request. We cannot predict the scope or ultimate outcome of this procedure or whether any Brazilian governmental authority will open an investigation into Pride’s involvement in this matter, or if a proceeding were opened, the scope or ultimate outcome of any such investigation.


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Any violation of the FCPA, OFAC regulations, the UKBA or other applicable anti-corruption laws by us, our affiliated entities or their respective officers, directors, employees and agents could in some cases provide a customer with termination rights under a contract and result in substantial fines, sanctions, civil and/or criminal penalties and curtailment of operations in certain jurisdictions and could adversely affect our financial condition, operating results, cash flows or the availability of funds under our revolving credit facility. Further, we may incur significant costs and consume significant internal resources in our efforts to detect, investigate and resolve actual or alleged violations.

Increasing regulatory complexity could adversely impact the costs associated with our offshore drilling operations.

Increases in regulatory requirements, particularly in the U.S. Gulf of Mexico, could significantly increase our costs.  In recent years, we have seen several significant regulatory changes that have affected the way we operate in the U.S. Gulf of Mexico.

Hurricanes Katrina and Rita in 2005 and Hurricanes Gustav and Ike in 2008 caused damage to a number of rigs in the Gulf of Mexico. Rigs that were moved off location by the storms damaged platforms, pipelines, wellheads and other drilling rigs. As a result of jackup rig fitness requirements during hurricane seasons issued by BSEE and its predecessor agency, jackup rigs in the U.S. Gulf of Mexico are required to operate with a higher air gap (the space between the water level and the bottom of the rig's hull) during hurricane season, effectively reducing the water depth in which they can operate. The guidelines also provide for enhanced information and data requirements from oil and gas companies operating in the U.S. Gulf of Mexico.

Following the 2010 Macondo well incident in the U.S. Gulf of Mexico, the U.S. Department of the Interior issued Notices to Lessees, implementing new requirements and/or guidelines that are applicable to drilling operations in the U.S. Gulf of Mexico. Current or future Notice to Lessees or other rules, directives and regulations may further impact our customers' ability to obtain permits and commence or continue deep or shallow water operations in the U.S. Gulf of Mexico. In 2016, BSEE promulgated the 2016 Well Control Rule imposing new requirements for well-control and blowout prevention equipment that could increase our costs and cause delays in our operations due to unavailability of associated equipment. In May 2018, BSEE proposed revisions to the 2016 Well Control Rule. This proposed rule would revise requirements for well design, well control, casing, cementing, real-time monitoring and subsea containment. The revisions are targeted to ensure safety and environmental protection while correcting errors in the 2016 rule and reducing certain unnecessary regulatory burdens imposed under the existing regulations. The proposed revisions have not yet been finalized.

Also, as a result of the Macondo well incident, BSEE and its predecessor agency promulgated regulations regarding SEMS. Although only operators are currently required to have a SEMS, the SEMS regulations require written agreements between operators and contractors regarding the contractors’ support of the operators' safety and environmental policies at the worksite, including requirements for personnel training and written safe work practices. In addition, BSEE has in the past stated that future rulemaking may require offshore drilling contractors to implement their own SEMS programs. The current SEMS regulations and the possibility of additional SEMS rules for contractors could expose us to increased costs.

In 2012, BSEE issued an IPD for use by BSEE inspectors in INCs to contractors operating under BSEE jurisdiction on the Outer Continental Shelf of the U.S. Gulf of Mexico. The stated purpose of the policy was to provide for consistency in application of BSEE enforcement authority by establishing guidelines for issuance of INCs to contractors in addition to operators. The policy indicated that BSEE’s enforcement actions would continue to focus primarily on lessees and operators, but that “in appropriate circumstances” BSEE also would issue INCs to contractors for “serious violations” of BSEE regulations. Following federal court decisions successfully challenging the scope of BSEE’s jurisdiction over offshore contractors, this IPD has been removed from the list of IPDs on the BSEE website. If this judicial precedent stands, it may reduce regulatory and civil litigation liability exposures.

Since 2014, the United States Coast Guard has proposed new regulations that would impose GPS equipment and positioning requirements for MODUs and jackup 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

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for all vessels and facilities that are subject to the MTSA, including our rigs. In 2016, BSEE adopted the 2016 Well Control Rule, which will be implemented in phases over the next several years. This new rule includes more stringent design requirements for well-control equipment used in offshore drilling operations. As described above, revisions to this rule have been proposed by BSEE, which could reduce the regulatory burden of the rule. We are continuing to evaluate the cost and effect that these new rules will have on our operations. However, based on our current assessment of the rules, we do not expect to incur significant costs to comply with the rule. Implementation of further guidelines and regulations may subject us to increased costs and limit the operational capabilities of our rigs.

Any new or additional regulatory, legislative, permitting or certification requirements in the U.S., including laws and regulations that have or may impose increased financial responsibility, oil spill abatement contingency plan capability requirements, or additional operational requirements and certifications, could materially adversely affect our financial position, operating results or cash flows.

We anticipate that government regulation in other countries where we operate may follow the U.S. in regard to enhanced safety and environmental regulation, which could also result in governments imposing sanctions on contractors when operators fail to comply with regulations that impact drilling operations. Even if not a requirement in these countries, most international operating companies, and many others, are voluntarily complying with some or all of the U.S. inspections and safety and environmental guidelines when operating outside the U.S. Such additional governmental regulation and voluntary compliance by operators could increase the cost of our operations and expose us to greater liability.

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

Our operations are subject to laws and regulations controlling the discharge of materials into the environment, pollution, contamination and hazardous waste disposal or otherwise relating to the protection of the environment. Environmental laws and regulations specifically applicable to our business activities could impose significant liability on us for damages, clean-up costs, fines and penalties in the event of oil spills or similar discharges of pollutants or contaminants into the environment or improper disposal of hazardous waste generated in the course of our operations. To date, such laws and regulations have not had a material adverse effect on our operating results, and we have not experienced an accident that has exposed us to material liability arising out of or relating to discharges of pollutants into the environment.  However, the legislative, judicial and regulatory response to a well incident could substantially increase our and our customers' liabilities.  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.
    
The International Convention on Oil Pollution Preparedness, Response and Cooperation, the International Convention on Civil Liability for Oil Pollution Damage 1992, the U.K. Merchant Shipping Act 1995, Marpol 73/78 (the International Convention for the Prevention of Pollution from Ships), the U.K. Merchant Shipping (Oil Pollution Preparedness, Response and Co-operation Convention) Regulations 1998, as amended, and other related legislation and regulations and the OPA 90, as amended, the Clean Water Act, and other U.S. federal statutes applicable to us and our operations, as well as similar statutes in Texas, Louisiana, other coastal states and other non-U.S. jurisdictions, address oil spill prevention, reporting and control and have significantly expanded potential liability, fine and penalty exposure across many segments of the oil and gas industry.

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. Although OPA 90 provides for certain limits of liability, such limits are not applicable where there is any safety violation or where gross negligence is involved. Failure to comply with these statutes and regulations, including OPA 90, may subject us to civil or criminal enforcement action, which may not be covered by contractual indemnification or insurance and could have a material adverse effect on our financial position, operating results or cash flows. Further, remedies under the Clean Water Act and related legislation and OPA 90 do not preclude claims under state regulations or civil claims for damages to third parties under state laws.

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High profile and catastrophic events, including the 2010 Macondo well incident, have heightened governmental and environmental concerns about the risks associated with offshore oil and gas drilling. We are adversely affected by restrictions on drilling in certain areas in which we operate, including policies and guidelines regarding the approval of drilling permits, restrictions on development and production activities, and directives and regulations that have and may further impact our operations. From time to time, legislative and regulatory proposals have been introduced that would materially limit or prohibit offshore drilling in certain areas, or that would increase the liabilities or costs associated with offshore drilling. If new laws are enacted, or if government actions are taken that restrict or prohibit offshore drilling in our principal areas of operation or that impose environmental or other 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, our financial position, operating results or cash flows could be materially adversely affected.

Laws and governmental regulations may add to costs, limit our drilling activity or reduce demand for our drilling services.

Our operations are affected by political developments and by laws and regulations that relate directly to the oil and gas industry. The offshore contract drilling industry is dependent on demand for services from the oil and gas industry. Accordingly, we will be directly affected by the approval and adoption of laws and regulations limiting or curtailing exploration and development drilling for oil and natural gas for economic, environmental, safety and other policy reasons. Furthermore, we may be required to make significant capital expenditures or incur substantial additional costs to comply with new governmental laws and regulations. It is also possible that legislative and regulatory activity could adversely affect our operations by limiting drilling opportunities or significantly increasing our operating costs.

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

Governments around the world are increasingly focused on enacting laws and regulations regarding climate change and regulation of greenhouse gases. Lawmakers and regulators in the jurisdictions where we operate have proposed or enacted regulations requiring reporting of greenhouse gas emissions and the restriction thereof, including increased fuel efficiency standards, carbon taxes or cap and trade systems, restrictive permitting, and incentives for renewable energy. In addition, efforts have been made and continue to be made in the international community toward the adoption of international treaties or protocols that would address global climate change issues and impose reductions of hydrocarbon-based fuels, including plans developed in connection with the Paris climate conference in December 2015 and the Katowice climate conference in December 2018. Laws or regulations incentivizing or mandating the use of alternative energy sources such as wind power and solar energy have also been enacted in certain jurisdictions. Additionally, numerous large cities globally and several countries have adopted programs to mandate or incentivize the conversion from internal combustion engine powered vehicles to electric-powered vehicles and placed restrictions on non-public transportation. Such policies or other laws, regulations, treaties and international agreements related to greenhouse gases and climate change may negatively impact the price of oil relative to other energy sources, reduce demand for hydrocarbons, limit drilling in the offshore oil and gas industry, or otherwise unfavorably impact our business, our suppliers and our customers, and result in increased compliance costs and additional operating restrictions, all of which would have a material adverse impact on our business. In addition, there have also been efforts in recent years to influence the investment community, including investment advisors and certain sovereign wealth, pension and endowment funds, promoting divestment of fossil fuel equities and pressuring lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Such environmental activism and initiatives aimed at limiting climate change and reducing air pollution could ultimately interfere with our business activities and operations and our access to capital.

In addition to potential impacts on our business resulting from climate-change legislation or regulations, our business also could be negatively affected by climate-change related physical changes or changes in weather patterns. An increase in severe weather patterns could result in damages to or loss of our rigs, impact our ability to conduct our operations and/or result in a disruption of our customers’ operations. Finally, increasing attention to the risks of climate change has resulted in an increased possibility of lawsuits or investigations brought by public and private entities

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against oil and natural gas companies in connection with their greenhouse gas emissions. Should we be targeted by any such litigation or investigations, we may incur liability, which, to the extent that societal pressures or political 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. The ultimate impact of greenhouse gas emissions-related agreements, legislation and measures on our company’s financial performance is highly uncertain because we are unable to predict with certainty, for a multitude of individual jurisdictions, the outcome of political decision-making processes and the variables and tradeoffs that inevitably occur in connection with such processes.

Geopolitical events, terrorist attacks, piracy and military action could affect the markets for our services and have a material adverse effect on our business and cost and availability of insurance.

Geopolitical events have resulted in military actions, terrorist, pirate and other armed attacks, civil unrest, political demonstrations, mass strikes and government responses. Military action by the United States or other nations could escalate, and acts of terrorism, piracy, kidnapping, extortion, acts of war, violence, civil war or general disorder may initiate or continue. Such acts could be directed against companies such as ours. Such developments have caused instability in the world’s financial and insurance markets in the past. In addition, these developments could lead to increased volatility in prices for oil and natural gas and could affect the markets for our services, particularly to the extent that such events take place in regions with significant oil and natural gas reserves, refining facilities or transportation infrastructure, such as the Persian Gulf area. Insurance premiums could increase and coverage for these kinds of events may be unavailable in the future. Any or all of these effects could have a material adverse effect on our financial position, operating results or cash flows.

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.

We currently have two ultra-deepwater drillships under construction. In the future, we may construct additional rigs and continue to upgrade the capability and extend the service lives of our existing rigs. As a result of current market conditions, we may seek to delay delivery of our rigs under construction. During the third quarter of 2019, we entered into amendments to our construction agreements with the shipyard for the VALARIS DS-13 and VALARIS DS-14 rigs to provide for two-year extensions of the delivery date of each rig into 2021 and 2022, respectively. During periods of heightened rig construction projects, shipyards and third-party equipment vendors may be under significant resource constraints to meet delivery obligations. Such constraints may lead to substantial delivery and commissioning delays, equipment failures and/or quality deficiencies. Furthermore, new drilling rigs may face start-up or other operational complications following completion of construction, upgrades or maintenance. Other unexpected difficulties, including equipment failures, design or engineering problems, could result in significant downtime at reduced or zero day rates or the cancellation or termination of drilling contracts.

Rig construction, upgrade, life extension and repair projects are subject to the risks of delay or cost overruns inherent in any large construction project, including the following:

failure of third-party equipment to meet quality and/or performance standards, 

delays in equipment deliveries or shipyard construction, 

shortages of materials or skilled labor, 

damage to shipyard facilities or construction work-in-progress, including damage resulting from fire, explosion, flooding, severe weather, terrorism, war or other armed hostilities, 

unforeseen design or engineering problems, including those relating to the commissioning of newly designed equipment, 

unanticipated actual or purported change orders, 

strikes, labor disputes or work stoppages, 


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financial or operating difficulties of equipment vendors or the shipyard while constructing, enhancing, upgrading, improving or repairing a rig or rigs, 

unanticipated cost increases, 

foreign currency exchange rate fluctuations impacting overall cost, 

inability to obtain the requisite permits or approvals, 

client acceptance delays, 

disputes with shipyards and suppliers, 

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

claims of force majeure events, and 

additional risks inherent to shipyard projects in a non-U.S. location.

With respect to VALARIS DS-13 and VALARIS DS-14, if we were to secure contracts for such rigs, we would be subject to the risk of delays and other hazards impacting the viability of such contracts, which could have a material adverse effect on our financial position, operating results or cash flows.

In addition, we believe the costs required to reactivate a stacked rig and return the rig to drilling service are significant. Depending on the length of time that a rig has been stacked, we may incur significant costs to restore the rig to drilling capability, which may also include capital expenditures due to the possible technological obsolescence of the rig. 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. We can provide no assurance that we will have access to adequate or economical sources of capital to fund the return of stacked rigs to drilling service.

Failure to recruit and retain skilled personnel could adversely affect our operations and financial results.

We require skilled personnel to operate our drilling rigs and to provide technical services and support for our business. Historically, competition for the labor required for drilling operations and construction projects was intense as the number of rigs activated, added to worldwide fleets or under construction increased, leading to shortages of qualified personnel in the industry. During such periods of intensified competition, it is more difficult and costly to recruit and retain qualified employees, especially in foreign countries that require a certain percentage of national employees. The recent prolonged industry downturn may further reduce the number of qualified personnel available. If competition for labor were to intensify in the future, we could experience an increase in operating expenses, with a resulting reduction in net income, and our ability to fully staff and operate our rigs could be negatively affected.

We may be required to maintain or increase existing levels of compensation to retain our skilled workforce, especially if our competitors raise their wage rates. We also are subject to potential legislative or regulatory action that may impact working conditions, paid time off or other conditions of employment. If such labor trends continue, they could further increase our costs or limit our ability to fully staff and operate our rigs.

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

Outside of the U.S., we are often subject to collective bargaining agreements that require periodic salary negotiations, which usually result in higher personnel expenses and other benefits. Efforts have been made from time to time to unionize other portions of our workforce. In addition, we have been subjected to strikes or work stoppages and other labor disruptions in certain countries. Additional unionization efforts, new collective bargaining agreements or work stoppages could materially increase our costs, reduce our revenues or limit our flexibility.


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Certain legal obligations require us to contribute certain amounts to retirement funds or other benefit plans and restrict our ability to dismiss employees. Future regulations or court interpretations established in the countries in which we conduct our operations could increase our costs and materially adversely affect our business, financial position, operating results or cash flows.

We have historically made substantial 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, which could adversely affect our financial condition, operating results or cash flows.

We have historically made substantial capital expenditures to maintain our fleet. These expenditures could increase as a result of changes in:

offshore drilling technology,

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,

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 relating to safety or 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 useful lives.

Additionally, in order to expand our fleet, we may require additional capital in the future. If we are unable to fund capital with cash flows from operations or proceeds from sales of non-core 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 changes in laws and regulations (or interpretation thereof) and by adverse market conditions resulting from, among others, general economic conditions, contingencies and uncertainties that are beyond our control. Similarly, when lenders and institutional investors reduce, and in some cases cease to provide, funding to industry borrowers, the liquidity and financial condition of us and our customers can be adversely impacted. 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 financial position, operating results or cash flows.


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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.

Our reliance on third-party suppliers, manufacturers and service providers to secure equipment, parts, components and sub-systems used in our operations exposes us to potential volatility in the quality, prices and availability of such items. Certain high-specification parts and equipment that we use in our operations may be available only from a small number of suppliers, manufacturers or service providers, or in some cases must be sourced through a single supplier, manufacturer or service provider. Recent industry consolidation has reduced the number of available suppliers. A disruption in the deliveries from such third-party suppliers, manufacturers or service providers, capacity constraints, production disruptions, price increases, quality control issues, recalls or other decreased availability of parts and equipment could adversely affect our ability to meet our commitments to customers, thus adversely impacting our operations and revenues and/or our operating costs.

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

In general, our costs 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 day rate based on stipulated cost increases or decreases, the timing and amount earned from these day rate adjustments may differ from our actual increase in costs and many contracts do not allow for such day rate adjustments. During times of reduced demand, reductions in costs may not be immediate 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 general, labor costs increase primarily due to higher salary levels and inflation. 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.

Our information technology systems are subject to cybersecurity risks and threats.

We depend on technologies, systems and networks to conduct our offshore and onshore operations, to collect payments from customers and to pay vendors and employees.  Despite our security measures, our information technology and infrastructure may be vulnerable to attacks by hackers or breached due to employee error, malfeasance or other disruptions. The risks associated with cyber incidents and attacks on our information technology systems could include disruptions of certain systems on our rigs; other impairments of our ability to conduct our operations; loss of intellectual property, proprietary information or customer and vendor data; disruption of our or our customers' operations; and increased costs to prevent, respond to or mitigate cybersecurity events.   Any such breach or attack could result in injury to people, loss of control of, or damage to, our (or our customer's assets), or harm to the environment. Any such breach or attack could also compromise our networks or our customers' and vendors' networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information could result in legal claims or proceedings, including under data privacy laws and regulations such as the European Union General Data Protection Regulation, disrupt our operations and damage our reputation, which could adversely affect our financial position, operating results or cash flows. In the past, we have experienced data security breaches resulting from unauthorized access to our systems, which to date have not had a material impact on our operations; however, there is no assurance that such impacts will not be material in the future.

The accounting method for our 2024 Convertible Notes could have a material effect on our reported financial results.
Under U.S. GAAP, we must separately account for the liability and equity components of convertible debt instruments, such as our 3.00% exchangeable senior notes due 2024 (the “2024 Convertible Notes”) in a manner that reflects the issuer’s economic interest cost. The equity component representing the conversion feature is recorded in additional paid-in capital within the shareholders’ equity section of our consolidated balance sheet. The carrying value of the debt component is recorded with a corresponding discount that will result in a significant amount of non-cash interest expense from the accretion of the discounted carrying value up to the principal amount over the term of the

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2024 Convertible Notes. The equity component is not remeasured if we continue to meet certain conditions for equity classification under U.S. GAAP, including maintaining the ability to settle the 2024 Convertible Notes entirely in shares. During periods in which we are unable to meet the conditions for equity classification, the equity component or a portion thereof would be remeasured through earnings, which could adversely affect our operating results.

Upon conversion of the 2024 Convertible Notes, holders will receive cash, our Class A ordinary shares or a combination thereof, at our election. Our intent is to settle the principal amount of the 2024 Convertible Notes in cash upon conversion. If the conversion value exceeds the principal amount (i.e., our share price exceeds the exchange price on the date of conversion), we expect to deliver shares equal to our conversion obligation in excess of the principal amount. During each respective reporting period that our average share price exceeds the exchange price, an assumed number of shares required to settle the conversion obligation in excess of the principal amount will be included in the denominator for our computation of diluted earnings per share using the treasury stock method. If we are unable to demonstrate our intent to settle the principal amount in cash, or are otherwise unable to utilize the treasury stock method, our diluted earnings per share would be adversely affected. See Note 6 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information on our 2024 Convertible Notes.

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

Although Valaris plc is incorporated in the United Kingdom (and thus would generally be considered a “foreign” corporation (or non-U.S. tax resident)), the U.S. Internal Revenue Service (“IRS”) may assert that we should be treated as a U.S. corporation (and U.S. tax resident) pursuant to the rules under Section 7874 of the Internal Revenue Code (including as a result of the Atwood acquisition completed in 2017). While we do not believe we are appropriately treated as a U.S. corporation pursuant to these rules, the rules are complex and the determination is subject to factual uncertainties. If the IRS successfully challenged our status as a foreign corporation, significant adverse tax consequences would result for us and for certain of our shareholders.

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

Even if we are currently treated as a foreign corporation for U.S. federal income tax purposes, Section 7874 of the Internal Revenue Code and U.S. Treasury Regulations promulgated thereunder, including temporary Treasury Regulations, may adversely affect our ability to engage in certain future acquisitions of U.S. businesses in exchange for our equity, which may affect the tax efficiencies that otherwise might be achieved in such potential future transactions.

Governments may pass laws that subject us to additional taxation or may challenge our tax positions, which could adversely affect our financial position, operating results or cash flows.

There is increasing uncertainty with respect to tax laws, regulations and treaties, and the interpretation and enforcement thereof that may affect our business. The Organization for Economic Cooperation and Development (“OECD”) has issued its final reports on base erosion and profit shifting, which generally focus on situations where profits are earned in low-tax jurisdictions, or payments are made between affiliates from jurisdictions with high tax rates to jurisdictions with lower tax rates. Certain countries within which we operate have recently enacted changes to their tax laws in response to the OECD recommendations or otherwise and these and other countries may enact changes to their tax laws or practices in the future (prospectively or retroactively), which may have a material adverse effect on our financial position, operating results or cash flows. U.S. federal income tax reform legislation enacted in late 2017 introduced significant changes to U.S. income tax law, including a reduction in the statutory income tax rate from 35% to 21%, a one-time transition tax on deemed repatriation of deferred foreign income, a base erosion anti-abuse tax that effectively imposes a minimum tax on certain payments to non-U.S. affiliates, new and revised rules relating to the current taxation of certain income of foreign subsidiaries and revised rules associated with limitations on the deduction of interest.

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In addition, our tax positions are subject to audit by U.K., U.S. and other foreign tax authorities. Such tax authorities may disagree with our interpretations or assessments of the effects of tax laws, treaties or regulations or their applicability to our corporate structure or certain transactions we have undertaken. Even if we are successful in maintaining our tax positions, we may incur significant expenses in defending our positions and contesting claims asserted by tax authorities. If we are unsuccessful in defending our tax positions, the resulting assessments or rulings could significantly impact our consolidated income taxes in past or future periods.

During 2019, we received income tax assessments totaling approximately €142.0 million (approximately $159.0 million converted using the current period-end exchange rates) and A$101 million (approximately $70.9 million converted at current period-end exchange rates) from taxing authorities in Luxembourg and Australia, respectively. See Note 12 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on income taxes.

During the third quarter of 2019, we made a A$42 million payment (approximately $29 million at then-current exchange rates) to the Australian tax authorities to litigate the assessment. We are also contesting the Luxembourg tax assessments. We may make a payment to the Luxembourg tax authorities in advance of the final resolution of these assessments. Although the outcome of such assessments cannot be predicted with certainty, unfavorable outcomes could have a material adverse effect on our liquidity.

As a result of these uncertainties, as well as changes in the administrative practices and precedents of tax authorities or other matters (such as changes in applicable accounting rules) that increase the amounts we have provided for income taxes or deferred tax assets and liabilities in our consolidated financial statements, we cannot provide any assurances as to what our consolidated effective income tax rate will be in future periods.  If we are unable to mitigate the negative consequences of any change in law, audit or other matters, this could cause our consolidated income taxes to increase and cause a material adverse effect on our financial position, operating results or cash flows.

Our consolidated effective income tax rate may vary substantially from one reporting period to another.

We cannot provide any assurances as to what our future consolidated effective income tax rate will be because of, among other matters, uncertainty regarding the nature and extent of our business activities in any particular jurisdiction in the future and the tax laws of such jurisdictions, as well as potential changes in U.K., U.S. and other foreign tax laws, regulations or treaties or the interpretation or enforcement thereof, changes in the administrative practices and precedents of tax authorities or other matters (such as changes in applicable accounting rules) that increase the amounts we have provided for income taxes or deferred tax assets and liabilities in our consolidated financial statements. In addition, as a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in the overall level of our income and changes in tax laws, our consolidated effective income tax rate may vary substantially from one reporting period to another. In periods of declining profitability, our income tax expense may not decline proportionately with income. Further, we may continue to incur income tax expense in periods in which we operate at a loss. Income tax rates imposed in the tax jurisdictions in which our subsidiaries conduct operations vary, as does the tax base to which the rates are applied. In some cases, tax rates may be applicable to gross revenues, statutory or negotiated deemed profits or other bases utilized under local tax laws, rather than to net income. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. If we are unable to mitigate the negative consequences of any change in law, audit, business activity or other matters, this could cause our consolidated effective income tax rate to increase and cause a material adverse effect on our financial position, operating results or cash flows.


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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.

Stamp duty and/or SDRT are imposed in the U.K. on certain transfers of chargeable securities (which include shares in companies incorporated in the U.K.) at a rate of 0.5% of the consideration paid for the transfer. Certain transfers of shares to depositary receipt facilities or clearance systems providers are charged at a higher rate of 1.5%.

Pursuant to arrangements that we entered into with the Depository Trust Company (“DTC”), our Class A ordinary shares are eligible to be held in book entry form through the facilities of DTC. Transfers of shares held in book entry form through DTC will not attract a charge to stamp duty or SDRT in the U.K. A transfer of the shares from within the DTC system out of DTC and any subsequent transfers that occur entirely outside the DTC system will attract a charge to stamp duty at a rate of 0.5% of any consideration, which is payable by the transferee of the shares. Any such duty must be paid (and the relevant transfer document stamped by Her Majesty's Revenue & Customs (“HMRC”)) before the transfer can be registered in the share register of Valaris plc. If a shareholder decides to redeposit shares into DTC, the redeposit will attract SDRT at a rate of 1.5% of the value of the shares.

We have put in place arrangements with our transfer agent to require that shares held in certificated form cannot be transferred into the DTC system until the transferor of the shares has first delivered the shares to a depository specified by us so that SDRT may be collected in connection with the initial delivery to the depository. Any such shares will be evidenced by a receipt issued by the depository. Before the transfer can be registered in our share register, the transferor will also be required to provide the transfer agent sufficient funds to settle the resultant liability for SDRT, which will be charged at a rate of 1.5% of the value of the shares.

Following decisions of the European Court of Justice and the U.K. First-tier Tax Tribunal, HMRC announced that it would not seek to apply a charge to stamp duty or SDRT on the issuance of shares (or, where it is integral to the raising of new capital, the transfer of new shares) into a depositary receipt facility or clearance system provider, such as DTC. Further, in its 2017 Autumn Budget the U.K. government announced that it would not reintroduce the Stamp Duty and Stamp Duty Reserve Tax 1.5% charge on the issue of shares (and transfers integral to capital raising) into overseas clearance services and depositary receipt systems following the U.K.’s exit from the European Union. However, it is possible that the U.K. government may change or enact laws applicable to stamp duty or SDRT, which could have a material effect on the cost of trading in our 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.

The facilities of DTC are widely-used for rapid electronic transfers of securities between participants within the DTC system, which include numerous major international financial institutions and brokerage firms. Currently, all trades of our Class A ordinary shares on the NYSE are cleared and settled on the facilities of DTC. Our Class A ordinary shares are, at present, eligible for deposit and clearing within the DTC system, pursuant to arrangements with DTC whereby DTC accepted our Class A ordinary shares for deposit, clearing and settlement services, and we agreed to indemnify DTC for any stamp duty and/or SDRT that may be assessed upon it as a result of its service as a clearance system provider for our Class A ordinary shares. However, DTC retains sole discretion to cease to act as a clearance system provider for our Class A ordinary shares at any time.

If DTC determines at any time that our shares are no longer eligible for deposit, clearing and settlement services within its facilities, our shares may become ineligible for continued listing on a U.S. securities exchange, and trading in such shares would be disrupted. In this event, DTC has agreed it will provide us advance notice and assist us, to the extent possible, with efforts to mitigate adverse consequences. While we would pursue alternative arrangements to preserve our listing and maintain trading, any such disruption could have a material adverse effect on the trading price of our Class A ordinary shares.


39



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

Because we are a public limited company incorporated under the Laws of England and Wales, investors could experience difficulty enforcing judgments obtained against us in U.S. courts. In addition, it may be more difficult (or impossible) to bring some types of claims against us in courts in England than it would be to bring similar claims against a U.S. company in a U.S. court.
 
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.

Directors of Delaware and other U.S. corporations may issue, without further shareholder approval, shares of common stock authorized in their certificates of incorporation that were not already issued or reserved.  The business corporation laws of Delaware and other U.S. states also provide substantial flexibility in establishing the terms of preferred stock. However, English law provides that a board of directors of a U.K. public limited company may only allot shares with the prior authorization of an ordinary resolution of the company’s shareholders, which authorization must state the maximum amount of shares that may be allotted under it and specify the date on which it will expire, which must not be more than five years from the date on which the shareholder resolution is passed. An ordinary resolution was passed by shareholders at our last annual general meeting in 2019 to authorize the allotment of up to a prescribed amount of additional shares until the conclusion of the next annual general meeting or the close of business on August 19, 2020 (whichever is earlier). An ordinary resolution will be put to shareholders at our next annual shareholder meeting seeking their approval to renew the board's authority to allot up to a prescribed amount of shares for an additional term.

English law also generally provides shareholders pre-emption rights over new shares that are issued for cash. However, it is possible, where the board of directors is generally authorized to allot shares, to exclude pre-emption rights by a special resolution of the shareholders or by a provision in the articles of association. Such exclusion of pre-emption rights will commonly cease to have effect at the same time as the general allotment authority to which it relates is revoked or expires.  If the general allotment authority is renewed, the authority excluding pre-emption rights may also be renewed by a special resolution of the shareholders. A special resolution was passed, in conjunction with an allotment authority at our last annual general meeting in 2019, to disapply pre-emption rights in respect of new shares up to a prescribed amount until the conclusion of the next annual general meeting or the close of business on August 19, 2020 (whichever is earlier). Special resolutions will be put to shareholders at our next annual shareholder meeting seeking their approval to renew the board's authority to disapply pre-emption rights in respect of new shares up to a prescribed amount for an additional term.

English law prohibits us from conducting "on-market purchases" as our shares will not be traded on a “recognized investment exchange”. English law also generally prohibits a company from repurchasing its own shares by way of "off-market purchases" without the approval by a special resolution of the shareholders of the terms of the contract by which the purchase(s) is affected. Such approval may only last for a maximum period of five years after the date on which the resolution is passed. A special resolution was passed at our annual shareholder meeting in May 2018 to permit us to make "off-market" purchases of our own shares pursuant to certain purchase agreements for a five-year term.

We can provide no assurances that the shareholder approvals required for the matters described above will be forthcoming. If all or any of such approvals are not granted, our flexibility with respect to certain capital management matters could be reduced which could, in turn, deprive our shareholders of substantial benefits.

Our articles of association contain anti-takeover provisions.

Certain provisions of our articles of association have anti-takeover effects, such as the ability to issue shares under the Rights Plan (as defined therein). These provisions are intended to ensure that any takeover or change of control of the Company is conducted in an orderly manner, all shareholders of the Company are treated equally and

40



fairly and receive an optimum price for their shares and the long-term success of the Company is safeguarded. Under English law, it may not be possible to implement these provisions in all circumstances.

The Company is not subject to the U.K.'s Code on Takeovers and Mergers (the “Code”).

The Code only applies to an offer for a public company that is registered in the U.K. (or the Channel Islands or the Isle of Man) and the securities of which are not admitted to trading on a regulated market in the U.K. (or the Channel Islands or the Isle of Man) if the company is considered by the takeover panel (the "Takeover Panel") to have its place of central management and control in the U.K. (or the Channel Islands or the Isle of Man). This is known as the "residency test." The test for central management and control under the Code is different from that used by the U.K. tax authorities. Under the Code, the Takeover Panel will look to where the majority of the directors of the company are residents for the purposes of determining where the company has its place of central management and control. Accordingly, the Takeover Panel has previously indicated that the Code does not apply to the Company and the Company's shareholders therefore do not have the benefit of the protections the Code affords, including, but not limited to, the requirement that a person who acquires an interest in shares carrying 30% or more of the voting rights in the Company must make a cash offer to all other shareholders at the highest price paid in the 12 months before the offer was announced.

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

Under English law, we are only able to declare dividends and return funds to our shareholders out of the accumulated distributable reserves on our statutory balance sheet. Distributable reserves are a company’s accumulated, realized profits, so far as not previously utilized by distribution or capitalization, less its accumulated, realized losses, so far as not previously written off in a reduction or reorganization of capital duly made. Realized profits are created through the remittance of profits of certain subsidiaries to our parent company in the form of dividends.

English law also provides that a public company can only make a distribution if, among other things (a) the amount of its net assets (that is, the total excess of assets over liabilities) is not less than the total of its called up share capital and non-distributable reserves and (b) if, and to the extent that, the distribution does not reduce the amount of its net assets to less than that total.
 
We may be unable to remit the profits of our subsidiaries in a timely or tax efficient manner. If at any time we do not have sufficient distributable reserves to declare and pay quarterly dividends, we may undertake a reduction in the capital of the Company, in addition to the reduction in capital taken in 2014, to reduce the amount of our share capital and non-distributable reserves and to create a corresponding increase in our distributable reserves out of which future distributions to shareholders can be made. To comply with English law, a reduction of capital would be subject to (a) approval of shareholders at a general meeting by special resolution; (b) confirmation by an order of the English Courts and (c) the Court order being delivered to and registered by the Registrar of Companies in England. If we were to pursue a reduction of capital of the Company as a course of action, and failed to obtain the necessary approvals from shareholders and the English Courts, we may undertake other efforts to allow the Company to declare dividends and return funds to shareholders.

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

Publicly traded companies have increasingly become subject to campaigns by activist investors advocating corporate actions such as actions related to environment, social and governance (“ESG”) matters, financial restructuring, increased borrowing, dividends, share repurchases or even sales of assets or the entire company. Responding to proxy contests and other actions by such activist investors or others in the future could be costly and time-consuming, disrupt our operations and divert the attention of our Board of Directors and senior management from the pursuit of our business strategies, which could adversely affect our results of operations and financial condition. Additionally, perceived uncertainties as to our future direction as a result of investor activism or changes to the composition of the Board of Directors may lead to the perception of a change in the direction of our business, instability or lack of continuity which

41



may be exploited by our competitors, cause concern to our current or potential customers, and make it more difficult to attract and retain qualified personnel. If customers choose to delay, defer or reduce transactions with us or transact with our competitors instead of us because of any such issues, then our revenue, earnings and operating cash flows could be adversely affected. In addition, the trading price of our shares could experience periods of increased volatility as a result of investor activism.

During 2019, one of our shareholders, who acquired and may continue to own a material portion of our outstanding shares, publicly stated its intent to initiate a proxy contest. Pursuant to a cooperation and support agreement, such shareholder nominated a representative who was appointed to our Board of Directors in February 2020. It is possible such shareholder, after the expiration of the cooperation and support agreement, or future activist investors may attempt to affect the actions described above or acquire control over us, engage in proxy solicitations and advance shareholder proposals.

In addition, we have received correspondence from purported holders of our debt securities alleging, among other things, breach of fiduciary duty and fraudulent conveyance, including with respect to our recently completed internal reorganization and our internal cash management system. Such holders and other holders of such debt securities may commence litigation against us based on those or other claims. We believe these allegations are without merit and, if litigation is commenced, we intend to defend ourselves vigorously. Even if we are successful in defending against such claims, however, we may expend significant management time and attention and funds to defend against such claims. Any adverse judgment against us could have a material adverse impact on our business, operations and financial condition.

Item 1B.  Unresolved Staff Comments

None.

42



Item 2.  Properties

Contract Drilling Fleet

The following table provides certain information about the rigs in our drilling fleet by reportable segment as of February 13, 2020:
 
 
Rig Name
 
 
  Rig Type
 
 
Year Built/
Rebuilt
 
 
 
Design      
 
   Maximum
 Water Depth/
Drilling Depth
 
 
  Location   
 
 
Status    
Floaters
 
 
 
 
 
 
 
 
 
 
VALARIS DS-3
Drillship
 
2010
 
Dynamically Positioned
 
10,000'/40,000'
 
Spain
Preservation stacked(1)
VALARIS DS-4
Drillship
 
2010
 
Dynamically Positioned
 
10,000'/40,000'
 
Spain
Available
VALARIS DS-5
Drillship
 
2011
 
Dynamically Positioned
 
10,000'/40,000'
 
Spain
Preservation stacked(1)
VALARIS DS-6
Drillship
 
2012
 
Dynamically Positioned
 
10,000'/40,000'
 
Spain
Available
VALARIS DS-7
Drillship
 
2013
 
Dynamically Positioned
 
10,000'/40,000'
 
Egypt
Under contract
VALARIS DS-8
Drillship
 
2015
 
Dynamically Positioned
 
10,000'/40,000'
 
Angola
Under contract
VALARIS DS-9
Drillship
 
2015
 
Dynamically Positioned
 
10,000'/40,000'
 
Brazil
Under contract
VALARIS DS-10
Drillship
 
2018
 
Dynamically Positioned
 
10,000'/40,000'
 
Nigeria
Under contract
VALARIS DS-11
Drillship
 
2013
 
Dynamically Positioned
 
12,000'/40,000'
 
Spain
Available
VALARIS DS-12
Drillship
 
2013
 
Dynamically Positioned
 
12,000'/40,000'
 
Egypt
Under contract
VALARIS DS-13
Drillship
 
Under construction
 
Dynamically Positioned
 
12,000'/40,000'
 
South Korea
Under construction(2)
VALARIS DS-14
Drillship
 
Under construction
 
Dynamically Positioned
 
12,000'/40,000'
 
South Korea
Under construction(2)
VALARIS DS-15
Drillship
 
2014
 
Dynamically Positioned
 
12,000'/40,000'
 
Gulf of Mexico
Under contract
VALARIS DS-16
Drillship
 
2014
 
Dynamically Positioned
 
12,000'/40,000'
 
Gulf of Mexico
Under contract
VALARIS DS-17
Drillship
 
2014
 
Dynamically Positioned
 
12,000'/40,000'
 
Spain
Available
VALARIS DS-18
Drillship
 
2015
 
Dynamically Positioned
 
12,000'/40,000'
 
Gulf of Mexico
Under contract
VALARIS 5004
Semisubmersible
 
1982/2001/2014
 
F&G Enhanced Pacesetter
 
1,500'/25,000'
 
Mediterranean
Under contract
VALARIS 8500
Semisubmersible
 
2008
 
Dynamically Positioned
 
8,500'/35,000'
 
Gulf of Mexico
Preservation stacked(1)
VALARIS 8501
Semisubmersible
 
2009
 
Dynamically Positioned
 
8,500'/35,000'
 
Gulf of Mexico
Preservation stacked(1)
VALARIS 8502
Semisubmersible
 
2010/2012
 
Dynamically Positioned
 
8,500'/35,000'
 
Gulf of Mexico
Preservation stacked(1)
VALARIS 8503
Semisubmersible
 
2010
 
Dynamically Positioned
 
8,500'/35,000'
 
Gulf of Mexico
Under contract
VALARIS 8504
Semisubmersible
 
2011
 
Dynamically Positioned
 
8,500'/35,000'
 
Malaysia
Available
VALARIS 8505
Semisubmersible
 
2012
 
Dynamically Positioned
 
8,500'/35,000'
 
Mexico
Under contract
VALARIS 8506
Semisubmersible
 
2012
 
Dynamically Positioned
 
8,500'/35,000'
 
Gulf of Mexico
Preservation stacked(1)
VALARIS DPS-1
Semisubmersible
 
2012
 
Dynamically Positioned
 
10,000'/35,000'
 
Australia
Under contract
VALARIS MS-1
Semisubmersible
 
2011
 
F&G ExD Millennium
 
8200'/32,000'
 
Malaysia
Available
 
 
 
 
 
 
 
 
 
 
 
Jackups
 
 
 
 
 
 
 
 
 
 
VALARIS JU-22
Jackup
 
1980
 
LT 116-C
 
250'/25,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-36
Jackup
 
1981
 
LT 116-C
 
250'/25,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-37
Jackup
 
1981
 
LT 116-C
 
250'/25,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-54
Jackup
 
1982/1997/2014
 
F&G L-780 MOD II-C
 
300'/25,000'
 
Saudi Arabia
Under contract
VALARIS JU-67
Jackup
 
1976/2005
 
MLT 84-CE
 
400'/30,000'
 
Indonesia
Under contract
VALARIS JU-70
Jackup
 
1981/1996/2014
 
Hitachi K1032N
 
250'/30,000
 
United Kingdom
Preservation stacked(1)
VALARIS JU-71
Jackup
 
1982/1995/2012
 
Hitachi K1032N
 
225'/25,000'
 
United Kingdom
Preservation stacked(1)
VALARIS JU-72
Jackup
 
1981/1996
 
Hitachi K1025N
 
225'/25,000'
 
United Kingdom
Under contract

43



Rig Name
Rig Type
 
Year Built/
Rebuilt
 
Design      
 
   Maximum
 Water Depth/
Drilling Depth
 
Location   
Status
Jackups
 
 
 
 
 
 
 
 
 
 
VALARIS JU-75
Jackup
 
1999
 
MLT Super 116-C
 
400'/30,000'
 
Gulf of Mexico
Under contract
VALARIS JU-76
Jackup
 
2000
 
MLT Super 116-C
 
350'/30,000'
 
Saudi Arabia
Under contract
VALARIS JU-84
Jackup
 
1981/2005/2012
 
MLT 82-SD-C
 
250'/25,000'
 
Saudi Arabia
Under contract
VALARIS JU-87
Jackup
 
1982/2006
 
MLT 116-C
 
350'/25,000'
 
Gulf of Mexico
Under contract
VALARIS JU-88
Jackup
 
1982/2004/2014
 
MLT 82-SD-C
 
250'/25,000'
 
Saudi Arabia
Under contract
VALARIS JU-92
Jackup
 
1982/1996
 
MLT 116-C
 
225'/25,000'
 
United Kingdom
Under contract
VALARIS JU-100
Jackup
 
1987
 
MLT 150-88-C
 
328'/25,000'
 
United Kingdom
Under contract
VALARIS JU-101
Jackup
 
2000
 
KFELS MOD V-A
 
400'/30,000'
 
United Kingdom
Under contract
VALARIS JU-102
Jackup
 
2002
 
KFELS MOD V-A
 
400'/30,000'
 
Gulf of Mexico
Under contract
VALARIS JU-104
Jackup
 
2002
 
KFELS MOD V-B
 
400'/30,000'
 
UAE
Available
VALARIS JU-105
Jackup
 
2002
 
KFELS MOD V-B
 
400'/30,000'
 
Singapore
Preservation stacked(1)
VALARIS JU-106
Jackup
 
2005
 
KFELS MOD V-B
 
400'/30,000'
 
Indonesia
Under contract
VALARIS JU-107
Jackup
 
2006
 
KFELS MOD V-B
 
400'/30,000'
 
Australia
Under contract
VALARIS JU-108
Jackup
 
2007
 
KFELS MOD V-B
 
400'/30,000'
 
Saudi Arabia
Under contract
VALARIS JU-109
Jackup
 
2008
 
KFELS MOD V-Super B
 
350'/35,000'
 
Angola
Under contract
VALARIS JU-110
Jackup
 
2015
 
KFELS MOD V-B
 
400'/30,000'
 
Qatar
Under contract
VALARIS JU-111
Jackup
 
2003
 
KFELS MOD V-B
 
400'/36,000'
 
Malta
Cold stacked
VALARIS JU-113
Jackup
 
2012
 
Pacific Class 400
 
400'/30,000'
 
Philippines
Cold stacked
VALARIS JU-114
Jackup
 
2012
 
Pacific Class 400
 
400'/30,000'
 
Philippines
Cold stacked
VALARIS JU-115
Jackup
 
2013
 
Pacific Class 400
 
400'/30,000'
 
Thailand
Under contract
VALARIS JU-116
Jackup
 
2008
 
LT 240- C
 
375'/35,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-117
Jackup
 
2009
 
LT 240- C
 
350'/35,000'
 
Trinidad
Under contract
VALARIS JU-118
Jackup
 
2011
 
LT 240- C
 
350'/35,000
 
Trinidad
Available
VALARIS JU-120
Jackup
 
2013
 
KFELS Super A
 
400'/40,000'
 
United Kingdom
Under contract
VALARIS JU-121
Jackup
 
2013
 
KFELS Super A
 
400'/40,000'
 
Netherlands
Under contract
VALARIS JU-122
Jackup
 
2014
 
KFELS Super A
 
400'/40,000'
 
United Kingdom
Under contract
VALARIS JU-123
Jackup
 
2019
 
KFELS Super A
 
400'/40,000'
 
United Kingdom
Under contract
VALARIS JU-140
Jackup
 
2016
 
Cameron Letourneau Super 116E
 
400'/30,000'
 
Saudi Arabia
Under contract
VALARIS JU-141
Jackup
 
2016
 
Cameron Letourneau Super 116E
 
400'/30,000'
 
Saudi Arabia
Under contract
VALARIS JU-142
Jackup
 
2008
 
LT Super 116-E
 
400'/30,000'
 
Malta
Cold stacked
VALARIS JU-143
Jackup
 
2010
 
LT Super 116-E
 
400'/30,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-144
Jackup
 
2010
 
LT Super 116-E
 
400'/30,000'
 
Mexico
Under contract
VALARIS JU-145
Jackup
 
2010
 
LT Super 116-E
 
400'/30,000'
 
Gulf of Mexico
Available
VALARIS JU-146
Jackup
 
2011
 
LT Super 116-E
 
400'/30,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-147
Jackup
 
2013
 
LT Super 116-E
 
400'/30,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-148
Jackup
 
2013
 
LT Super 116-E
 
400'/30,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-247
Jackup
 
1998
 
LT Super Gorilla
 
400'/30,000'
 
United Kingdom
Under contract
VALARIS JU-248
Jackup
 
2000
 
LT Super Gorilla
 
400'/30,000'
 
United Kingdom
Under contract
VALARIS JU-249
Jackup
 
2002
 
LT Super Gorilla
 
400'/30,000'
 
United Kingdom
Under contract
VALARIS JU-250
Jackup
 
2003
 
LT Super Gorilla XL
 
400'/30,000'
 
Saudi Arabia
Leased to ARO drilling
VALARIS JU-290
Jackup
 
2010
 
KEFLS N Class
 
400'/30,000'
 
Norway
Under contract
VALARIS JU-291
Jackup
 
2011
 
KEFLS N Class
 
400'/30,000'
 
Norway
Under contract
VALARIS JU-292
Jackup
 
2011
 
KEFLS N Class
 
400'/30,000'
 
Norway
Under contract

(1) 
Prior to stacking, upfront steps are taken to preserve the rig. This may include a quayside power source to dehumidify key equipment and/or provide electric current to the hull to prevent corrosion. Also, certain

44



equipment may be removed from the rig for storage in a temperature-controlled environment. While stacked, large equipment that remains on the rig is periodically inspected and maintained by Valaris personnel. These steps are designed to reduce time and lower cost to reactivate the rig when market conditions improve.

(2) 
Rig is currently under construction and is not contracted.

The equipment on our drilling rigs includes engines, draw works, derricks, pumps to circulate drilling fluid, well control systems, drill string and related equipment. The engines power a top-drive mechanism that turns the drill string and drill bit so that the hole is drilled by grinding subsurface materials, which are then returned to the rig by the drilling fluid. The intended water depth, well depth and geological conditions are the principal factors that determine the size and type of rig most suitable for a particular drilling project.
 
Floater rigs consist of drillships and semisubmersibles. Drillships are purpose-built maritime vessels outfitted with drilling apparatus.  Drillships are self-propelled and can be positioned over a drill site through the use of a computer-controlled propeller or "thruster" dynamic positioning systems.  Our drillships are capable of drilling in water depths of up to 12,000 feet and are suitable for deepwater drilling in remote locations because of their superior mobility and large load-carrying capacity.  Although drillships are most often used for deepwater drilling and exploratory well drilling, drillships can also be used as a platform to carry out well maintenance or completion work such as casing and tubing installation or subsea tree installations.
    
Semisubmersibles are MODUs with pontoons and columns that are partially submerged at the drilling location to provide added stability during drilling operations. Semisubmersibles are held in a fixed location over the ocean floor either by being anchored to the sea bottom with mooring chains or dynamically positioned by computer-controlled propellers or "thrusters" similar to that used by our drillships.  Moored semisubmersibles are most commonly used for drilling in water depths of 4,499 feet or less.  However, VALARIS MS-1, which is a moored semisubmersible, is capable of deepwater drilling in water depths greater than 5,000 feet.  Dynamically positioned semisubmersibles generally are outfitted for drilling in deeper water depths and are well-suited for deepwater development and exploratory well drilling. Further, we have three hybrid semisubmersibles, VALARIS 8503, VALARIS 8504 and VALARIS 8505, which leverage both moored and dynamically positioned configurations. This hybrid design provides multi-faceted drilling solutions to customers with both shallow water and deepwater requirements.
 
Jackup rigs stand on the ocean floor with their hull and drilling equipment elevated above the water on connected leg supports. Jackups are generally preferred over other rig types in shallow water depths of 400 feet or less, primarily because jackups provide a more stable drilling platform with above water well-control equipment. Our jackups are of the independent leg design where each leg can be fixed into the ocean floor at varying depths and equipped with a cantilever that allows the drilling equipment to extend outward from the hull over fixed platforms enabling safer drilling of both exploratory and development wells. The jackup hull supports the drilling equipment, jacking system, crew quarters, storage and loading facilities, helicopter landing pad and related equipment and supplies.
 
Over the life of a typical rig, many of the major systems are replaced due to normal wear and tear or technological advancements in drilling equipment. We believe all our rigs are in good condition. As of February 21, 2020, we owned all rigs in our fleet. We also manage the drilling operations for two rigs owned by third-parties.
 
We lease our executive offices in London, England in addition to office space in Houston, Aberdeen, Abu Dhabi, Australia, Dubai, Indonesia, Malaysia, Malta, Mexico, Nigeria, The Netherlands, Saudi Arabia, Singapore, Thailand, Vietnam and Qatar. We own offices and other facilities in Louisiana, Angola, Australia and Brazil.


45



Item 3.  Legal Proceedings
  
Shareholder Derivative Lawsuit

On August 20, 2019, plaintiff Xiaoyuan Zhang, a purported Valaris shareholder, filed a class action lawsuit on behalf of Valaris shareholders against Valaris plc and certain of our executive officers, alleging violations of federal securities laws. The complaint cites general statements in press releases and SEC filings and alleges that the defendants made false or misleading statements or failed to disclose material information regarding the performance of our ultra-deepwater segment, among other things.

The complaint asserts claims on behalf of a class of investors who purchased Valaris plc shares between April 11, 2019 and July 31, 2019. Under applicable law, the court appointed a lead plaintiff and lead counsel. We anticipate that an amended complaint will be filed in the second quarter of 2020. We strongly disagree and intend to vigorously defend against these claims. At this time, we are unable to predict the outcome of these matters or the extent of any resulting liability.

DSA Dispute

On January 4, 2016, Petrobras sent a notice to us declaring the drilling services agreement with Petrobras (the "DSA") for VALARIS DS-5, a drillship ordered from Samsung Heavy Industries, a shipyard in South Korea ("SHI"), void effective immediately, reserving its rights and stating its intention to seek any restitution to which it may be entitled. The previously disclosed arbitral hearing on liability related to the matter was held in March 2018. Prior to the arbitration tribunal issuing its decision, we and Petrobras agreed in August 2018 to a settlement of all claims relating to the DSA. No payments were made by either party in connection with the settlement agreement. The parties agreed to normalize business relations, and the settlement agreement provides for our participation in current and future Petrobras tenders on the same basis as all other companies invited to these tenders. No losses were recognized during 2018 with respect to this settlement as all disputed receivables with Petrobras related to the DSA were fully reserved in 2015.  See Item 1 “Legal Proceedings” in our quarterly report on Form 10-Q for the quarter ended June 30, 2018 for further information about the DSA dispute.

In April 2016, we initiated separate arbitration proceedings in the U.K. against SHI for the losses incurred in connection with the foregoing Petrobras arbitration and certain other losses relating to the DSA. In January 2018, the arbitration tribunal for the SHI matter issued an award on liability fully in our favor. The January 2018 arbitration award provides that SHI is liable to us for $10.0 million or damages that we can prove. We submitted our claim for damages to the tribunal, and the arbitral hearing on damages owed to us by SHI took place during the first quarter of 2019.

In May 2019, the arbitration tribunal for the SHI matter awarded us $180.0 million in damages, in addition to the right to claim interest and costs, in connection with this matter. In June 2019, we and SHI filed separate applications with the English High Court to seek leave to appeal the damages awarded.

In December 2019, the English High Court denied the parties’ applications for leave to appeal the tribunal’s $180.0 million damages award. Following this decision, the parties reached an agreement and SHI paid us $200.0 million in cash. Collection of this payment resulted in the recognition of a gain of the same amount, which is included in other, net, in our consolidated statement of operations for the year ended December 31, 2019. This payment, along with the previously disclosed settlement and normalization of our business relationship with Petrobras, concludes our dispute surrounding VALARIS DS-5.



46



Environmental Matters
 
We are currently subject to pending notices of assessment relating to spills of drilling fluids, oil, brine, chemicals, grease or fuel from drilling rigs operating offshore Brazil from 2008 to 2017, pursuant to which the governmental authorities have assessed, or are anticipated to assess, fines. We have contested these notices and appealed certain adverse decisions and are awaiting decisions in these cases. Although we do not expect final disposition of these assessments to have a material adverse effect on our financial position, operating results and cash flows, there can be no assurance as to the ultimate outcome of these assessments. A $145,000 liability related to these matters was included in accrued liabilities and other on our consolidated balance sheet as of December 31, 2019.
 
We currently are subject to a pending administrative proceeding initiated during 2009 by a Spanish government authority seeking payment in an aggregate amount of approximately $3.0 million for an alleged environmental spill originating from VALARIS 5006 while it was operating offshore Spain. Our customer has posted guarantees with the Spanish government to cover potential penalties. Additionally, we expect to be indemnified for any payments resulting from this incident by our customer under the terms of the drilling contract. A criminal investigation of the incident was initiated during 2010 by a prosecutor in Tarragona, Spain, and the administrative proceedings have been suspended pending the outcome of this investigation. In May 2019, we were informed that the criminal investigation has been completed. We have not received any indication from the Spanish government if or when the administrative proceedings will resume.
 
We intend to vigorously defend ourselves in the administrative proceeding and any criminal investigation. At this time, we are unable to predict the outcome of these matters or estimate the extent to which we may be exposed to any resulting liability. Although we do not expect final disposition of this matter to have a material adverse effect on our financial position, operating results and cash flows, there can be no assurance as to the ultimate outcome of the proceedings.

Other Matters

In addition to the foregoing, we are named defendants or parties in certain other lawsuits, claims or proceedings incidental to our business and are involved from time to time as parties to governmental investigations or proceedings, including matters related to taxation, arising in the ordinary course of business. Although the outcome of such lawsuits or other proceedings cannot be predicted with certainty and the amount of any liability that could arise with respect to such lawsuits or other proceedings cannot be predicted accurately, we do not expect these matters to have a material adverse effect on our financial position, operating results and cash flows.

Item 4.  Mine Safety Disclosures
 
    Not applicable.

47



PART II

Item 5.
Market for Registrant's Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities
Market Information
Our Class A ordinary shares are traded on the NYSE under the ticker symbol "VAL." Many of our shareholders hold shares electronically, all of which are owned by a nominee of DTC. We had 131 shareholders of record on February 1, 2020.
Dividends
 
Our Board of Directors declared a $0.01 quarterly cash dividend, on a pre-Reverse Stock Split basis, for the first quarter of 2019. Starting in the second quarter of 2019, our Board of Directors determined that we will not pay a regular quarterly cash dividend. The declaration and amount of future dividends is at the discretion of our Board of Directors and could change in future periods.

Our revolving credit facility prohibits us from paying dividends in excess of $0.01 per share per fiscal quarter. Dividends in excess of this amount would require the amendment or waiver of such provision.

Exchange Controls

There are no U.K. government laws, decrees or regulations that restrict or affect the export or import of capital, including but not limited to, foreign exchange controls on remittance of dividends on our ordinary shares or on the conduct of our operations.

U.K. Taxation
 
The following paragraphs are intended to be a general guide to current U.K. tax law and what is understood to be HMRC practice applying as of the date of this report (both of which are subject to change at any time, possibly with retrospective effect) in respect of the taxation of capital gains, the taxation of dividends paid by us and stamp duty and SDRT on the transfer of our shares. In addition, the following paragraphs relate only to persons who for U.K. tax purposes are beneficial owners of the shares.

These paragraphs may not relate to certain classes of holders or beneficial owners of shares, such as our employees or directors, persons who are connected with us, persons who could be treated for U.K. tax purposes as holding their shares as carried interest, insurance companies, charities, collective investment schemes, pension schemes, trustees or persons who hold shares other than as an investment, or U.K. resident individuals who are not domiciled in the U.K. or who are subject to split-year treatment.

These paragraphs do not describe all of the circumstances in which shareholders may benefit from an exemption or relief from taxation. It is recommended that all shareholders obtain their own taxation advice. In particular, any shareholders who are non-U.K. resident or domiciled are advised to consider the potential impact of any relevant double tax treaties, including the Convention between the United States of America and the United Kingdom for the Avoidance of Double Taxation with respect to Taxes on Income, to the extent applicable.

U.K. Taxation of Dividends
 
U.K. Withholding Tax - Dividends paid by us will not be subject to any withholding or deduction for, or on account of, U.K. tax, irrespective of the residence or the individual circumstances of the shareholders.


48



U.K. Income Tax - An individual shareholder who is resident in the U.K. may, depending on his or her individual circumstances, be subject to U.K. income tax on dividends received from us. An individual shareholder who is not resident in the U.K. will not be subject to U.K. income tax on dividends received from us, unless that shareholder carries on (whether alone or in partnership) any trade, profession or vocation through a branch or agency in the U.K. and shares are used by, or held by or for, that branch or agency. In these circumstances, the non-U.K. resident shareholder may, depending on his or her individual circumstances, be subject to U.K. income tax on dividends received from us.

The tax treatment of dividends paid by the Company to individual shareholders is as follows:

dividends paid by the Company will not carry a tax credit,

all dividends received by an individual shareholder from the Company (or from other sources) will, except to the extent that they are earned through an Individual Savings Account, self-invested personal pension plan or other regime which exempts the dividends from income tax, form part of the shareholder's total income for income tax purposes,

a nil rate of income tax will apply to the first £2,000 of taxable dividend income received by an individual shareholder in the tax year 2019/2020 (the "Nil Rate Amount"), regardless of what tax rate would otherwise apply to that dividend income,

any taxable dividend income received by an individual shareholder in a tax year in excess of the Nil Rate Amount will be taxed at a special rate, as set out below, and

that tax will be applied to the amount of the dividend income actually received by the individual shareholder (rather than to a grossed-up amount).

Where a shareholder’s taxable dividend income for a tax year exceeds the Nil Rate Amount, the excess amount will, subject to the availability of any income tax personal allowance, be subject to income tax at the following rates for the tax year 2018/2019:

at the rate of 7.5%, to the extent that the excess amount falls below the threshold for the higher rate of income tax,

at the rate of 32.5%, to the extent that the excess amount falls above the threshold for the higher rate of income tax but below the threshold for the additional rate of income tax, or

at the rate of 38.1%, to the extent that the excess amount falls above the threshold for the additional rate of income tax.

In determining whether and, if so, to what extent the relevant dividend income falls above or below the threshold for the higher rate of income tax or, as the case may be, the additional rate of income tax, the shareholder’s total dividend income for the tax year in question (including the part within the Nil Rate Amount) will be treated as the highest part of the shareholder’s total income for income tax purposes.
    
U.K. Corporation Tax - Unless an exemption is available, as discussed below, a corporate shareholder that is resident in the U.K. will be subject to U.K. corporation tax on dividends received from us. A corporate shareholder that is not resident in the U.K. will not be subject to U.K. corporation tax on dividends received from us, unless that shareholder carries on a trade in the U.K. through a permanent establishment in the U.K. and the shares are used by, for or held by or for, the permanent establishment. In these circumstances, the non-U.K. resident corporate shareholder may, depending on its individual circumstances (and if no exemption is available), be subject to U.K. corporation tax on dividends received from us.


49



The main rate of corporation tax payable with respect to dividends received from us in the financial year 2019 is 19%. If dividends paid by us fall within any of the exemptions from U.K. corporation tax set out in Part 9A of the U.K. Corporation Tax Act 2009, the receipt of the dividend by a corporate shareholder generally will be exempt from U.K. corporation tax. Generally, the conditions for one or more of those exemptions from U.K. corporation tax on dividends paid by us should be satisfied, although the conditions that must be satisfied in any particular case will depend on the individual circumstances of the relevant corporate shareholder.

Shareholders that are regarded as small companies should generally be exempt from U.K. corporation tax on dividends received from us, unless the dividends are received as part of a tax advantage scheme. Shareholders that are not regarded as small companies should generally be exempt from U.K. corporation tax on dividends received from us on the basis that the shares should be regarded as non-redeemable ordinary shares. Alternatively, shareholders that are not small companies should also generally be exempt from U.K. corporation tax on dividends received from us if they hold shares representing less than 10% of our issued share capital, would be entitled to less than 10% of the profits available for distribution to our equity-holders and would be entitled on a winding up to less than 10% of our assets available for distribution to such equity-holders. In certain limited circumstances, the exemption from U.K. corporation tax will not apply to such shareholders if a dividend is made as part of a scheme that has a main purpose of falling within the exemption from U.K. corporation tax.

U.K. Taxation of Capital Gains
 
U.K. Withholding Tax - Capital gains accruing to non-U.K. resident shareholders on the disposal of shares will not be subject to any withholding or deduction for or on account of U.K. tax, irrespective of the residence or the individual circumstances of the relevant shareholder.

U.K. Capital Gains Tax - A disposal of shares by an individual shareholder who is resident in the U.K. may, depending on his or her individual circumstances, give rise to a taxable capital gain or an allowable loss for the purposes of U.K. capital gains tax (“CGT”). An individual shareholder who temporarily ceases to be resident in the U.K. for a period of five years or less and who disposes of his or her shares during that period of temporary non-residence may be liable for CGT on a taxable capital gain accruing on the disposal on his or her return to the U.K. under certain anti-avoidance rules.

An individual shareholder who is not resident in the U.K. will not be subject to CGT on capital gains arising on the disposal of their shares, unless that shareholder carries on a trade, profession or vocation in the U.K. through a branch or agency in the U.K. and the shares were acquired, used in or for the purposes of the branch or agency or used in or for the purposes of the trade, profession or vocation carried on by the shareholder through the branch or agency. In these circumstances, the relevant non-U.K. resident shareholder may, depending on his or her individual circumstances, be subject to CGT on chargeable gains arising from a disposal of his or her shares. The rate of CGT in the tax year 2019/2020 is:

10%, to the extent that the shareholder's total taxable gains and taxable income in a given year, including any chargeable gains arising from a disposal of his or her shares ("Total Taxable Gains and Income"), are less than or equal to the upper limit of the income tax basic rate band applicable to that shareholder in respect of that tax year (the "Band Limit"), and

20%, to the extent that the shareholder's Total Taxable Gains and Income are more than the Band Limit.

U.K. Corporation Tax - A disposal of shares by a corporate shareholder resident in the U.K. may give rise to a chargeable gain or an allowable capital loss for the purposes of U.K. corporation tax. A corporate shareholder not resident in the U.K. will not be liable for U.K. corporation tax on chargeable gains accruing on the disposal of its shares, unless that shareholder carries on a trade in the U.K. through a permanent establishment in the U.K. and the shares were acquired, used in or for the purposes of the permanent establishment or used in or for the purposes of the trade carried on by the shareholder through the permanent establishment. In these circumstances, the relevant non-

50



U.K. resident shareholder may, depending on its individual circumstances, be subject to U.K. corporation tax on chargeable gains arising from a disposal of its shares.

The financial year for U.K. corporation tax purposes runs from April 1 to March 31. The main rate of U.K. corporation tax on chargeable gains is 19% in the financial year 2019. Corporate shareholders may be entitled to an indexation allowance in computing the amount of a chargeable gain accruing on a disposal of the shares, which provides relief for the effects of inflation by reference to movements in the U.K. retail price index. Such indexation allowance is calculated only up to and including December 2017. From January 1, 2018, indexation allowance is frozen. Indexation allowance will be calculated for assets acquired before January 1, 2018, irrespective of the date of disposal of the asset.

If the conditions of the substantial shareholding exemption are satisfied in relation to a chargeable gain accruing to a corporate shareholder on a disposal of its shares, the chargeable gain will be exempt from U.K. corporation tax. The conditions of the substantial shareholding exemption that must be satisfied will depend on the individual circumstances of the relevant corporate shareholder. One of the conditions of the substantial shareholding exemption that must be satisfied is that the corporate shareholder must have held a substantial shareholding in the Company throughout a 12-month period beginning not more than six years before the day on which the disposal takes place. Ordinarily, a corporate shareholder will not be regarded as holding a substantial shareholding in us unless it (whether alone, or together with other group companies) holds more than 10% of our ordinary share capital.

U.K. Stamp Duty and SDRT
 
The discussion below relates to shareholders wherever resident but not to holders such as market makers, brokers, dealers and intermediaries, to whom special rules apply. Special rules also apply in relation to certain stock lending and repurchase transactions.

Transfer of Shares held in book entry form via DTC - A transfer of shares held in book entry (i.e., electronic) form within the facilities of the DTC system will not be subject to U.K. stamp duty or SDRT.

Transfers of Shares out of, or outside of, DTC - Subject to an exemption for certain low value transactions, a transfer of shares from within the DTC system out of that system or any transfer of shares that occurs entirely outside the DTC system generally will be subject to a charge to ad valorem U.K. stamp duty (normally payable by the transferee) at 0.5% of the purchase price of the shares (rounded up to the nearest multiple of £5). SDRT generally will be payable on an unconditional agreement to transfer such shares at 0.5% of the amount or value of the consideration for the transfer. However, such liability for SDRT generally will be cancelled and any SDRT paid will be refunded if the agreement is completed by a duly-stamped transfer within six years of either the date of the agreement or, if the agreement was conditional, the date when the agreement became unconditional.

We have put in place arrangements to require that shares held outside the facilities of DTC cannot be transferred into such facilities (including where shares are re-deposited into DTC by an existing shareholder) until the transferor of the shares has first delivered the shares to a depository we specify, so that stamp duty and/or SDRT may be collected in connection with the initial delivery to the depository. Before such transfer can be registered in our books, the transferor will be required to put the depository in funds to settle the resultant liability for stamp duty and/or SDRT, which will be 1.5% of the value of the shares, and to pay the transfer agent such processing fees as may be established from time to time.

Following decisions of the European Court of Justice and the U.K. First-tier Tax Tribunal, HMRC announced that it would not seek to apply a charge to stamp duty or SDRT on the issuance of shares (or, where it is integral to the raising of new capital, the transfer of new shares) into a depositary receipt facility or clearance system provider, such as DTC. Further, in its 2017 Autumn Budget, the U.K. government announced that it would not reintroduce the Stamp Duty and Stamp Duty Reserve Tax 1.5% charge on the issue of shares (and transfers integral to capital raising) into overseas clearance services and depositary receipt systems following the U.K.’s exit from the E.U. However, it is possible that the U.K. government may change or enact laws applicable to stamp duty or SDRT, which could have a material effect on the cost of trading in our shares.

51




The above statements are intended only as a general guide to the current U.K. stamp duty and SDRT position. Transfers to certain categories of persons are not liable to U.K. stamp duty or SDRT and transfers to others may be liable at a higher rate than discussed above.
 
Equity Compensation Plans

For information on shares issued or to be issued in connection with our equity compensation plans, see "Part III, Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters."

Issuer Repurchases of Equity Securities
 
The following table provides a summary of our repurchases of our equity securities during the quarter ended December 31, 2019.

Issuer Repurchases of Equity Securities
 
  
 
 
Period
 
Total Number of Securities Repurchased(1)
 
Average Price Paid per Security
 
Total Number of Securities Repurchased as Part of Publicly Announced Plans or Programs (2)   
 
Approximate Dollar Value of Securities that May Yet Be Repurchased Under Plans or Programs
October 1 - October 31 
 
5,090

 
$
4.87

 

 
$
500,000,000

November 1 - November 30
 
4,721

 
$
4.40

 

 
$
500,000,000

December 1 - December 31
 
16,585

 
$
4.45

 

 
$
500,000,000

Total 
 
26,396

 
$
4.52

 

 
 


(1)
During the quarter ended December 31, 2019, equity securities were repurchased from employees and non-employee directors by an affiliated employee benefit trust in connection with the settlement of income tax withholding obligations arising from the vesting of share awards.  Such securities remain available for re-issuance in connection with employee share awards.
(2) 
Our shareholders approved a repurchase program at our annual shareholder meeting held in May 2018. Subject to certain provisions under English law, including the requirement of Valaris plc to have sufficient distributable reserves, we may repurchase up to a maximum of $500.0 million in the aggregate from one or more financial intermediaries under the program, but in no case more than 16.3 million shares. The program terminates in May 2023. As of December 31, 2019, there had been no share repurchases under the repurchase program. Our revolving credit facility prohibits the repurchase of shares for cash, except in certain limited circumstances.


52



Performance Chart
    
The chart below presents a comparison of the five-year cumulative total return, assuming $100 invested on December 31, 2014 for Valaris plc, the Standard & Poor's SmallCap 600 Index, and a self-determined peer group. Total return assumes the reinvestment of dividends, if any, in the security on the ex-dividend date. The Standard & Poor's SmallCap 600 Index includes Valaris and has been included as a comparison. Since Valaris operates exclusively as an offshore drilling company, a self-determined peer group composed exclusively of major offshore drilling companies has been included as a comparison.* 

COMPARISON OF 5 YEAR CUMULATIVE TOTAL RETURN(1) 
Among Valaris plc, the S&P SmallCap 600 Index and Peer Group
A5YEARTOTALRETURNANALYSIS.JPG

(1) $100 invested on 12/31/14; includes the reinvestment of dividends in the same security on the ex-dividend date.

Copyright© 2020 S&P, a division of The McGraw-Hill Companies Inc. All rights reserved.
 
Fiscal Year Ended December 31,
 
2014
 
2015
 
2016
 
2017
 
2018
 
2019
Valaris plc
100.0

 
53.0

 
33.6

 
20.6

 
12.5

 
5.8

S&P SmallCap 600
100.0

 
96.6

 
120.6

 
134.7

 
121.6

 
146.9

Peer Group
100.0

 
56.4

 
53.1

 
37.1

 
22.0

 
17.3

____________________________________
*The self-determined peer group is weighted according to market capitalization at the beginning of each year and consists of the following companies: Transocean Ltd., Diamond Offshore Drilling Inc., Noble Corp., and Seadrill Ltd**.
**The return from Seadrill Ltd consists of the company's results prior to its Chapter 11 U.S. Bankruptcy Code restructuring in 2017 and after it emerged from bankruptcy in 2018.

53



Item 6.  Selected Financial Data

The financial data below should be read in conjunction with "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and our consolidated financial statements and notes thereto included in "Item 8. Financial Statements and Supplementary Data."

 
Year Ended December 31,
 
2019
 
2018
 
2017
 
2016
 
2015
  
(in millions, except per share amounts)
Consolidated Statement of Operations Data
 
 
 

 
 

 
 

 
 

Revenues
$
2,053.2

 
$
1,705.4

 
$
1,843.0

 
$
2,776.4

 
$
4,063.4

Operating expenses
 

 
 

 
 

 
 

 
 

Contract drilling (exclusive of depreciation)
1,806.0

 
1,319.4

 
1,189.5

 
1,301.0

 
1,869.6

Loss on impairment
104.0

 
40.3

 
182.9

 

 
2,746.4

Depreciation
609.7

 
478.9

 
444.8

 
445.3

 
572.5

General and administrative
188.9

 
102.7

 
157.8

 
100.8

 
118.4

Total operating expenses
2,708.6

 
1,941.3

 
1,975.0

 
1,847.1

 
5,306.9

Equity in Earnings of ARO
(12.6
)
 

 

 

 

Operating income (loss)
(668.0
)

(235.9
)

(132.0
)

929.3


(1,243.5
)
Other income (expense), net
604.2

 
(303.0
)
 
(64.0
)
 
68.2

 
(227.7
)
Income tax expense (benefit)
128.4

 
89.6

 
109.2

 
108.5

 
(13.9
)
Income (loss) from continuing operations
(192.2
)
 
(628.5
)

(305.2
)

889.0


(1,457.3
)
Income (loss) from discontinued operations, net(1)

 
(8.1
)
 
1.0

 
8.1

 
(128.6
)
Net income (loss)
(192.2
)
 
(636.6
)

(304.2
)

897.1


(1,585.9
)
Net (income) loss attributable to noncontrolling interests
(5.8
)
 
(3.1
)
 
0.5

 
(6.9
)
 
(8.9
)
Net income (loss) attributable to Valaris
$
(198.0
)
 
$
(639.7
)

$
(303.7
)

$
890.2


$
(1,594.8
)
Earnings (loss) per share – basic and diluted
 

 
 

 
 

 
 

 
 

Continuing operations
$
(1.14
)
 
$
(5.82
)
 
$
(3.66
)
 
$
12.40

 
$
(25.30
)
Discontinued operations

 
(.08
)
 

 
0.12

 
(2.20
)
 
$
(1.14
)
 
$
(5.90
)

$
(3.66
)

$
12.52


$
(27.50
)
Weighted-average shares outstanding
 

 
 

 
 

 
 

 
 

Basic and diluted
173.4

 
108.5

 
83.1

 
69.8

 
58.1

(1) 
See Note 13 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on discontinued operations.


54



 
Year Ended December 31,
 
2019
 
2018
 
2017
 
2016
 
2015
  
(in millions)
Consolidated Balance Sheet and Cash Flow Statement Data
 
 
 
 
 
 
 
 
 
Working capital
$
233.7

 
$
781.2

 
$
853.5

 
$
2,424.9

 
$
1,509.6

Total assets
$
16,931.2

 
$
14,023.7

 
$
14,625.9

 
$
14,374.5

 
$
13,610.5

Long-term debt
$
5,923.5

 
$
5,010.4

 
$
4,750.7

 
$
4,942.6

 
$
5,868.6

Valaris shareholders' equity
$
9,310.9

 
$
8,091.4

 
$
8,732.1

 
$
8,250.6

 
$
6,512.9

Cash flows from operating activities of continuing operations
$
(276.9
)
 
$
(55.7
)
 
$
259.4

 
$
1,077.4

 
$
1,697.9

 

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

INTRODUCTION

Our Business
 
We are a leading provider of offshore contract drilling services to the international oil and gas industry. Exclusive of two rigs under construction and one rig marked for retirement and classified as held-for-sale, we currently own and operate an offshore drilling rig fleet of 74 rigs, with drilling operations in almost every major offshore market across six continents. Inclusive of our rigs under construction, our rig fleet includes 16 drillships, eight dynamically positioned semisubmersible rigs, two moored semisubmersible rigs and 50 jackup rigs, nine of which are leased to our 50/50 joint venture with Saudi Aramco.  We operate the world's largest fleet amongst competitive rigs, including one of the newest ultra-deepwater fleets in the industry and a leading premium jackup fleet.
    
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 24 countries on six continents. The markets in which we operate include the Gulf of Mexico, Brazil, the Mediterranean, the North Sea, Norway, the Middle East, West Africa, Australia and Southeast Asia.

We provide drilling services on a day rate contract basis. Under day rate contracts, we provide an integrated service that includes the provision of a drilling rig and rig crews for which we receive a daily rate that may vary between the full rate and zero rate throughout the duration of the contractual term, depending on the operations of the rig. We also may receive lump-sum fees or similar compensation for the mobilization, demobilization and capital upgrades of our rigs. 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.

Rowan Transaction

On October 7, 2018, we entered into a transaction agreement (the "Transaction Agreement") with Rowan, and on April 11, 2019 (the "Transaction Date"), we completed our combination with Rowan pursuant to the Transaction Agreement (the "Rowan Transaction") and changed our name to Ensco Rowan plc. On July 30, 2019, we changed our name to Valaris plc. Rowan's financial results are included in our consolidated results beginning on the Transaction Date.

As a result of the Rowan Transaction, Rowan shareholders received 2.750 Valaris Class A ordinary shares for each Rowan Class A ordinary share, representing a value of $43.67 per Rowan share based on a closing price of $15.88 per Valaris share on April 10, 2019, the last trading day before the Transaction Date. Total consideration delivered in the Rowan Transaction consisted of 88.3 million Valaris shares with an aggregate value of $1.4 billion. All share and

55



per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split (as defined herein).

Prior to the Rowan Transaction, Rowan and Saudi Aramco formed a 50/50 joint venture to own, manage and operate drilling rigs offshore Saudi Arabia ("Saudi Aramco Rowan Offshore Drilling Company" or "ARO"). ARO currently owns a fleet of seven jackup rigs, leases another nine jackup rigs from us and has plans to purchase up to 20 newbuild jackup rigs over an approximate 10 year period. In January 2020, ARO ordered the first two newbuild jackups scheduled for delivery in 2022. The rigs we lease to ARO are done so through bareboat charter agreements whereby substantially all operating costs are incurred by ARO. All nine jackup rigs leased to ARO and all seven ARO-owned jackup rigs are under long-term contracts with Saudi Aramco. For additional information about our ARO joint venture, see Note 4 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data."

The Rowan Transaction enhanced the market leadership of the combined company with a fleet of high-specification floaters and jackups and positions us well to meet increasing and evolving customer demand. The increased scale, diversification and financial strength of the combined company provides us advantages to better serve our customers. Exclusive of two older jackup rigs marked for retirement, Rowan’s offshore rig fleet at the Transaction Date consisted of four ultra-deepwater drillships and 19 jackup rigs.

Reverse Stock Split

Upon closing of the Rowan Transaction, we effected a consolidation (being a reverse stock split under English law) whereby every four existing Valaris Class A ordinary shares, each with a nominal value of $0.10, were consolidated into one Class A ordinary share, each with a nominal value of $0.40 (the “Reverse Stock Split”). Our shares began trading on a reverse stock split-adjusted basis on April 11, 2019. All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split.

Our Industry

Operating results in the offshore contract drilling industry are highly cyclical and are directly related to the demand for drilling rigs and the available supply of drilling rigs. Low demand and excess supply can independently affect day rates and utilization of drilling rigs. Therefore, adverse changes in either of these factors can result in adverse changes in our industry. While the cost of moving a rig may cause the balance of supply and demand to vary somewhat between regions, significant variations between regions are generally of a short-term nature due to rig mobility.

Drilling Rig Demand

The decline in oil prices from 2014 highs led to a significant reduction in global demand for offshore drilling services. Customers significantly reduced their capital spending budgets, including the cancellation or deferral of existing programs, resulting in fewer contracting opportunities for offshore drilling rigs. Declines in capital spending levels, together with the oversupply of rigs from newbuild deliveries, resulted in significantly reduced day rates and utilization that led to one of the most severe downturns in the industry's history.

More recently, oil prices have increased meaningfully from the decade lows reached during 2016, with Brent crude averaging nearly $55 per barrel in 2017 and more than $70 through most of 2018, leading to signs of a gradual recovery in demand for offshore drilling services. However, macroeconomic and geopolitical headwinds triggered a decline in Brent crude prices in late 2018, from more than $85 per barrel to approximately $50 per barrel. In 2019, oil prices experienced a gradual recovery from this decline with Brent crude prices averaging approximately $64 per barrel before falling near $55 per barrel in early 2020.

While this market volatility will likely continue over the near-term, we expect long-term oil prices to remain at levels sufficient to support a continued gradual recovery in demand for offshore drilling services. However, uncertainty remains regarding global trade and other geopolitical tensions in the Middle East and China and their resulting impact on the global economy. Adverse changes in the macro-economic environment resulting from trade

56



discussions, geopolitical events or other factors, including the impact of the coronavirus on global trade, could have a significant adverse impact on global economic growth and ultimately the demand for our offshore drilling services.

We continue to observe improvements in the shallow-water market, particularly with respect to higher-specification rigs, as higher levels of customer demand and rig retirements have led to gradually increasing jackup utilization over the past year. Moreover, global floater utilization has increased as compared to a year ago due to a higher number of contracted rigs and lower global supply resulting from rig retirements. However, the floater recovery has lagged the jackup recovery as average contract durations remain relatively short-term and pricing improvements to date have been modest.

Despite the increase in customer activity, contract awards remain subject to an extremely competitive bidding process, and the corresponding pressure on operating day rates in recent periods has resulted in low margin contracts, particularly for floaters. Therefore, our results from operations may continue to decline over the near-term as current contracts with above-market rates expire and new contracts are executed at lower rates. We believe further improvements in demand coupled with a reduction in rig supply are necessary to improve the commercial landscape for day rates.

Drilling Rig Supply

Drilling rig supply continues to exceed drilling rig demand for both floaters and jackups. However, the decline in customer capital expenditure budgets over the past several years has led to a lack of contracting opportunities resulting in meaningful global fleet attrition. Since the beginning of the downturn, drilling contractors have retired approximately 135 floaters and 100 jackups. As demand for offshore drilling has slowly begun to improve, newer more capable rigs have been the first to obtain new contract awards, increasing the likelihood that older, less capable rigs do not return to the global active fleet.

Approximately 20 floaters older than 30 years are idle, 10 additional floaters older than 30 years have contracts expiring by the end of 2020 without follow-on work and a further five floaters aged between 15 and 30 years have been idle for more than two years. Operating costs associated with keeping these rigs idle as well as expenditures required to re-certify these aging rigs may prove cost prohibitive. Drilling contractors will likely elect to scrap or cold-stack some or all of these rigs.

Approximately 90 jackups older than 30 years are idle, and 60 jackups that are 30 years or older have contracts expiring by the end of 2020 without follow-on work. Expenditures required to re-certify these aging rigs may prove cost prohibitive and drilling contractors may instead elect to scrap or cold-stack these rigs. We expect jackup scrapping and cold-stacking to continue during 2020.

There are 26 newbuild drillships and semisubmersibles reported to be under construction, of which 16 are scheduled to be delivered before the end of 2020. Most newbuild floaters are uncontracted. Several newbuild deliveries have been delayed into future years, and we expect that more uncontracted newbuilds will be delayed or cancelled.

There are 51 newbuild jackups reported to be under construction, of which 41 are scheduled to be delivered before the end of 2020. Most newbuild jackups are uncontracted. Over the past year, some jackup orders have been cancelled, and many newbuild jackups have been delayed. We expect that scheduled jackup deliveries will continue to be delayed until more rigs are contracted.


57



Liquidity, Debt Maturities and Backlog

We proactively manage our capital structure in an effort to most effectively execute our strategic priorities and maximize value for shareholders. In support of these objectives, we are focused on our liquidity, debt levels and maturity profile and cost of capital. Over the past several years we have executed a number of financing transactions to improve our financial statement position and manage our debt maturities, including the July 2019 tender offers discussed below. Based on our balance sheet, our contractual backlog and $1.6 billion available under our credit facility, we expect to fund our anticipated 2020 liquidity needs, including negative operating cash flows, debt service and other contractual obligations, anticipated capital expenditures, as well as working capital requirements, from cash and short-term investments and funds borrowed under our credit facility or other future financing arrangements, including available shipyard financing options for our two drillships under construction.

Our credit facility is an integral part of our financial flexibility and liquidity. We also may rely on the issuance of debt and/or equity securities in the future to supplement our liquidity needs. In addition, we may seek to extend our maturities and reduce the overall principal amount of our debt through exchange offers or other liability management transactions. We have significant financial flexibility within our capital structure, including the ability to issue debt that would be structurally senior to our currently outstanding debt, on both an unsecured and secured basis, subject to restrictions contained in our existing debt arrangements. Our liability management efforts, if undertaken, may be unsuccessful or may not improve our financial position to the extent anticipated.

Our ability to maintain a sufficient level of liquidity to meet our financial obligations will also be dependent upon our future performance, which will be subject to general economic conditions, industry cycles and financial, business and other factors affecting our operations, many of which are beyond our control. For example, if we experience further deterioration in demand for offshore drilling, our ability to maintain a sufficient level of liquidity could be materially and adversely impacted, which could have a material adverse impact on our business, financial condition, results of operations, cash flows and our ability to repay or refinance our debt.

Cash and Debt

As of December 31, 2019, we had $6.5 billion in total principal debt outstanding, representing 41.2% of our total capitalization. We also had $97.2 million in cash and $1.6 billion undrawn capacity under our credit facility, which expires in September 2022.

In December 2019, we received $200.0 million in cash resulting from the settlement of a dispute with Samsung Heavy Industries. See Note 13 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data."

Effective upon closing of the Rowan Transaction, we amended our credit facility to, among other changes, increase the borrowing capacity. Previously, our credit facility had a borrowing capacity of $2.0 billion through September 2019 that declined to $1.3 billion through September 2020 and $1.2 billion through September 2022. Subsequent to the amendment our borrowing capacity is $1.6 billion through September 2022. The credit agreement governing the credit facility includes an accordion feature allowing us to increase the future commitments by up to an aggregate amount not to exceed $250.0 million.

As a result of the Rowan Transaction, we acquired the following debt: (1) $201.4 million in aggregate principal amount of 7.875% unsecured senior notes, which was repaid at maturity in August 2019, (2) $620.8 million in aggregate principal amount of 4.875% unsecured senior notes due 2022, (3) $398.1 million in aggregate principal amount of 4.75% unsecured senior notes due 2024, (4) $500.0 million in aggregate principal amount of 7.375% unsecured senior notes due 2025, (5) $400.0 million in aggregate principal amount of 5.4% unsecured senior notes due 2042 and (6) $400.0 million in aggregate principal amount of 5.85% unsecured senior notes due 2044. Upon closing of the Rowan Transaction, we terminated Rowan's outstanding credit facilities.


58



On June 25, 2019, we commenced cash tender offers for certain senior notes issued by us, Ensco International Incorporated and Rowan Companies, Inc., our wholly-owned subsidiaries. The tender offers expired on July 23, 2019, and we repurchased $951.8 million aggregate principal amount of notes for a total purchase price of approximately $724.1 million, plus accrued interest.

As of December 31, 2019, our principal debt maturities include $122.9 million in 2020, $113.5 million in 2021, $620.8 million in 2022 and $1.8 billion in 2024.

Backlog

As of December 31, 2019, our backlog was $2.5 billion as compared to $2.2 billion as of December 31, 2018. Our floater backlog declined $94.2 million and our jackup backlog increased $210.2 million. These changes resulted from the addition of backlog from the Rowan Transaction, new contract awards and contract extensions offset by revenues realized during the period. Our other segment backlog increased $154.4 million due to the addition of backlog from the Rowan Transaction related to the rigs leased to ARO.
    
Contract backlog includes the impact of drilling contracts signed or terminated after each respective balance sheet date but prior to filing our annual reports on February 21, 2020 and February 28, 2019, respectively.

BUSINESS ENVIRONMENT

Floaters

The floater contracting environment remains challenging due to limited demand and excess newbuild supply. Floater demand has declined significantly following the decline in commodity prices in 2014 which caused our customers to reduce capital expenditures, particularly for capital-intensive, long-lead deepwater projects, resulting in the cancellation and delay of drilling programs. During the past year, we have observed increased tendering activity that may translate into marginal improvements in near-term utilization; however, further improvements in demand and/or reductions in supply will be necessary before meaningful increases in utilization and day rates are realized.

During the first quarter of 2019, we executed a four-well contract for VALARIS DS-9 that commenced offshore Brazil in June 2019 and a six-month contract for VALARIS DS-7 that commenced offshore Egypt in April 2019. Additionally, we executed a two-well contract for VALARIS DPS-1 that is expected to commence in March 2020 and a four-well contract for VALARIS 8503 that commenced in July 2019.

During the second quarter of 2019, we executed a one-well contract for VALARIS DS-18 in the U.S. Gulf of Mexico that commenced in February 2020. We also entered into short-term contract extensions for VALARIS DS-12 and VALARIS DPS-1.

During the third quarter of 2019, we executed a four-well contract for VALARIS DS-12 that is expected to commence offshore Angola in April 2020, a one-well contract for VALARIS DS-15 that is expected to commence in the U.S. Gulf of Mexico in January 2020 and a one-well contract for VALARIS DS-4 that is expected to commence offshore Ghana in March 2020. We also extended contracts for VALARIS DPS-1 by seven-wells with an estimated duration of 420 days, VALARIS 8505 by three-wells, VALARIS DS-16 by approximately 180 days and VALARIS DS-7 by approximately 165 days. Additionally, we began marketing the VALARIS 5006 for sale and classified the rig as held-for-sale. As a result, we recognized an impairment charge of $88.2 million in our consolidated statement of operations.

During the fourth quarter of 2019, we executed a one-year contract extension for VALARIS DS-10. VALARIS DS-7 was awarded a five-well contract that is expected to commence in September and has an estimated duration of 320 days. VALARIS DS-18 was awarded a two-well contract that is expected to commence in July 2020 and has an estimated duration of 180 days. VALARIS DS-18 also had a contract extension due to the exercise of one-well option. VALARIS DS-15 was awarded two contracts, a one-well contract that commenced in November 2019 and a two-well

59



contract expected to commence in May 2020. VALARIS DS-15 also had a contract extension due to the exercise of a one-well priced option, the contract has an estimated duration of 45 days and is expected to commence in March 2020. VALARIS DS-12 and VALARIS MS-1 were awarded one-well contracts that are expected to commence in February 2020 and July 2020, respectively. We also executed a one-well contract for VALARIS DS-9 that is expected to commence in July 2020. We also entered into a short-term contract extension for VALARIS 8503.

During the fourth quarter of 2019, we sold VALARIS 5006 for scrap value resulting in an insignificant pre-tax gain. We also began marketing the VALARIS 6002 and classified the rig as held-for-sale on our December 31, 2019 consolidated balance sheet. The VALARIS 6002 was subsequently sold in January 2020 resulting in an insignificant pre-tax gain.

Jackups

Demand for jackups has improved with increased contracting activity observed over the past year, leading to slight improvements in day rates.

During the first quarter of 2019, we executed a nine-well contract for VALARIS JU-100 that commenced in November 2019. As a result, a previously disclosed contract for VALARIS JU-100 has been fulfilled by VALARIS JU-248. Additionally, we executed a three-well contract for VALARIS JU-121 that commenced in April 2019 and three-well and one-well contracts for VALARIS JU-72 and VALARIS JU-68, respectively, that commenced during May 2019. We also executed short-term contract extensions for VALARIS JU-101 and VALARIS JU-96.

With respect to the Rowan jackups, a six-month contract extension with a two-month option was executed for VALARIS JU-248 during the first quarter. Additionally, short-term contracts were executed for VALARIS JU-292, VALARIS JU-290 and VALARIS JU-144. The VALARIS JU-290 and VALARIS JU-292 contracts include four additional one-well priced options and two short-term option periods, respectively.

During the second quarter of 2019, we executed a two-year contract for VALARIS JU-120, a two-well contract for VALARIS JU-122, a forty-well P&A contract for VALARIS JU-72, a five-month contract for VALARIS JU-107, two one-well contracts for VALARIS JU-102 and a one-well contract for VALARIS JU-101. Additionally, we executed a two-year extension for VALARIS JU-109, a seven-month extension for VALARIS JU-104, a six-month extension for VALARIS JU-247, a three-month extension for VALARIS JU-96 and one-well extensions for VALARIS JU-118 and VALARIS JU-144.

During the second quarter of 2019, we scrapped ENSCO 97 and the Gorilla IV and recognized an insignificant pre-tax gain.

During the third quarter of 2019, we executed a four-well contract for VALARIS JU-248, an accommodation contract for VALARIS JU-290, a one-well contract for VALARIS JU-107 and a one-well contract for VALARIS JU-87 that commenced in September. We also extended the contracts for VALARIS JU-291 by two-wells, VALARIS JU-247 by approximately eight months and received short-term extensions for VALARIS JU-88, VALARIS JU-115, VALARIS JU-117, VALARIS JU-123 and VALARIS JU-248.

During the fourth quarter of 2019, we executed a 200-day contract for VALARIS JU-249 and a 21-well contract for VALARIS JU-87, both of which commenced in November 2019, and a one-well contract for VALARIS JU-75 that commenced in December 2019. We also executed a 12-well contract for VALARIS JU-144 that is expected to commence in April 2020, a six-well contract for VALARIS JU-292 that is expected to commence in May 2020, and a three-well contract for VALARIS JU-101 that is expected to commence in March 2020. VALARIS JU-107 had a contract extension due to the exercise of one-well option and was also warded a two-well contract that is expected to commence in June 2020. Additionally, we executed short-term contract extensions for VALARIS JU-115, VALARIS JU-117, VALARIS JU-122, and VALARIS JU-290.


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Additionally, in the fourth quarter of 2019, we sold VALARIS JU-42 for scrap value and recognized an insignificant gain. We also began marketing the VALARIS JU-68 and VALARIS JU-70 and classified the rigs as held-for-sale on our December 31, 2019 consolidated balance sheet. We recognized a pre-tax impairment charge of $10.2 million on the VALARIS JU-70. The VALARIS JU-68 was subsequently sold in January 2020 resulting in an insignificant pre-tax loss.

In July 2019, a well being drilled offshore Indonesia by one of our jackup rigs experienced a well-control event requiring the cessation of drilling activities. The operator could seek to terminate the contract under certain circumstances. If this drilling contract were to be terminated for cause, it would result in an approximate $8.5 million decrease in our backlog as of December 31, 2019. See Note 13 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data."

RESULTS OF OPERATIONS

The following table summarizes our consolidated results of operations for each of the years in the three-year period ended December 31, 2019 (in millions):
 
 
2019
 
2018
 
2017
Revenues
 
$
2,053.2

 
$
1,705.4

 
$
1,843.0

Operating expenses
 
 

 
 

 
 

Contract drilling (exclusive of depreciation)
 
1,806.0

 
1,319.4

 
1,189.5

Loss on impairment
 
104.0

 
40.3

 
182.9

Depreciation
 
609.7

 
478.9

 
444.8

General and administrative 
 
188.9

 
102.7

 
157.8

Total operating expenses
 
2,708.6

 
1,941.3

 
1,975.0

Equity in earnings of ARO
 
(12.6
)
 

 

Operating loss
 
(668.0
)
 
(235.9
)

(132.0
)
Other income (expense), net
 
604.2

 
(303.0
)
 
(64.0
)
Provision for income taxes 
 
128.4

 
89.6

 
109.2

Loss from continuing operations
 
(192.2
)
 
(628.5
)
 
(305.2
)
Income (loss) from discontinued operations, net
 

 
(8.1
)
 
1.0

Net loss
 
(192.2
)
 
(636.6
)
 
(304.2
)
Net (income) loss attributable to noncontrolling interests
 
(5.8
)
 
(3.1
)
 
.5

Net loss attributable to Valaris
 
$
(198.0
)
 
$
(639.7
)

$
(303.7
)
    
Overview

Year Ended December 31, 2019

Revenues increased by $347.8 million, or 20%, as compared to the prior year primarily due to $322.2 million of revenue earned by the Rowan rigs, $125.5 million due to revenues earned from our rigs leased to ARO and revenues earned from the Secondment Agreement and Transition Services Agreement, and $84.1 million due to the commencement of VALARIS DS-9, VALARIS JU-123, VALARIS JU-140 and VALARIS JU-141 drilling operations. This increase was partially offset by the sale of ENSCO 6001, VALARIS 5006 and ENSCO 97, which operated in the prior-year period, and lower average day rates across the remaining fleet.

Contract drilling expense increased by $486.6 million, or 37%, as compared to the prior year primarily due to $351.2 million of contract drilling expense incurred by the Rowan rigs, $57.0 million due to expenses incurred under the Secondment Agreement and by our rigs leased to ARO, $38.2 million due to the commencement of VALARIS DS-9, and $31.3 million due to the commencement of drilling operations for VALARIS JU-123, VALARIS JU-140

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and VALARIS JU-141. This increase was partially offset by the sale of ENSCO 6001, VALARIS 5006 and ENSCO 97, which operated in the prior-year period.

General and administrative expenses increased by $86.2 million, or 84%, as compared to the prior year period, primarily due to transaction and integration costs associated with the Rowan Transaction.

Year Ended December 31, 2018

Revenues declined by $137.6 million, or 7%, as compared to the prior year. The decline was primarily due to a decline in average day rates in both our floater and jackup fleets and the sale of several rigs during the year that operated in the year-ago period, partially offset by increased utilization and the addition of Atwood rigs to the fleet in late 2017.

Contract drilling expense increased by $129.9 million, or 11%, as compared to the prior year. The increase was primarily due to addition of rigs to the fleet from the acquisition of Atwood Oceanics, Inc. (Atwood) and the commencement of drilling operations for several of our newbuild rigs. This increase was partially offset by the sale of several rigs during the year that operated in the year-ago period and cost incurred during the prior year to settle a previously disclosed legal contingency.

Excluding the impact of $7.5 million of transaction costs during 2018 and $51.6 million of transaction costs during 2017 from the Atwood acquisition, general and administrative expenses declined by $11.0 million, or 10%, as compared to the prior year. The decline was primarily due to lower compensation costs and the recovery of certain legal costs awarded to us in connection with the SHI litigation.

Rig Counts, Utilization and Average Day Rates
   
The following table summarizes our offshore drilling rigs by reportable segment, rigs under construction and rigs held-for-sale as of December 31, 2019, 2018 and 2017:
 
 
2019
 
2018
 
2017
Floaters(1)
 
24
 
22
 
24
Jackups(2)
 
41
 
34
 
37
Other(3)
 
9
 
 
Under construction(4)
 
2
 
3
 
3
Held-for-sale(5)
 
3
 
 
1
Total Valaris
 
79
 
59
 
65
ARO(6)
 
7
 
 

(1) 
During 2019, we added VALARIS DS-18, VALARIS DS-17, VALARIS DS-16 and VALARIS DS-15 from the Rowan Transaction, sold VALARIS 5006 and classified VALARIS 6002 as held-for-sale. During 2018, we sold ENSCO 5005 and ENSCO 6001.

(2) 
During 2019, we added 10 jackups from the Rowan Transaction, exclusive of rigs leased to ARO that are included in Other, accepted delivery of VALARIS JU-123, classified VALARIS JU-68 and VALARIS JU-70 as held-for-sale and sold VALARIS JU-96 and ENSCO 97. During 2018, we sold ENSCO 80, ENSCO 81 and ENSCO 82.

(3) 
During 2019, we added nine jackups from the Rowan Transaction that are leased to ARO.

(4) 
During 2019, we accepted the delivery of VALARIS JU-123.


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(5) 
During 2019, we classified VALARIS JU-68, VALARIS JU-70 and VALARIS 6002 as held-for-sale. During 2018, we sold ENSCO 7500.

(6) 
This represents the seven rigs owned by ARO.

The following table summarizes our and ARO's rig utilization and average day rates from continuing operations by reportable segment for each of the years in the three-year period ended December 31, 2019. Rig utilization and average day rates include results for Rowan rigs and ARO from the transaction date through December 31, 2019:
 
 
2019
 
2018
 
2017
Rig Utilization(1)
 
 

 
 

 
 

Floaters
 
47%
 
46%
 
45%
Jackups
 
66%
 
63%
 
60%
Other(2)
 
100%
 
100%
 
100%
Total Valaris
 
63%
 
56%
 
55%
ARO
 
93%
 
—%
 
—%
Average Day Rates(3)
 
 
 
 

 
 
Floaters
 
$
218,837

 
$
248,395

 
$
327,736

Jackups
 
78,133

 
77,086

 
84,913

Other(2)
 
49,236

 
81,751

 
79,566

Total Valaris
 
$
108,313

 
$
128,365

 
$
153,306

ARO
 
$
71,170

 
$

 
$


(1) 
Rig utilization is derived by dividing the number of days under contract by the number of days in the period. Days under contract equals the total number of days that rigs have earned and recognized day rate revenue, including days associated with early contract terminations, compensated downtime and mobilizations. When revenue is deferred and amortized over a future period, for example when we receive fees while mobilizing to commence a new contract or while being upgraded in a shipyard, the related days are excluded from days under contract.

For newly-constructed or acquired rigs, the number of days in the period begins upon commencement of drilling operations for rigs with a contract or when the rig becomes available for drilling operations for rigs without a contract.

(2) 
Includes our two managed services contracts and our nine rigs leased to ARO under bareboat charter contracts.

(3) 
Average day rates are derived by dividing contract drilling revenues, adjusted to exclude certain types of non-recurring reimbursable revenues, lump-sum revenues and revenues attributable to amortization of drilling contract intangibles, by the aggregate number of contract days, adjusted to exclude contract days associated with certain mobilizations, demobilizations and shipyard contracts.

Detailed explanations of our operating results, including discussions of revenues, contract drilling expense and depreciation expense by segment, are provided below.

Operating Income by Segment

Prior to the Rowan Transaction, our business consisted of three operating segments: (1) Floaters, which included our drillships and semisubmersible rigs, (2) Jackups and (3) Other, which consisted only of our management services provided on rigs owned by third parties. Our Floaters and Jackups were also reportable segments.

As a result of the Rowan Transaction, we concluded that we would maintain the aforementioned segment structure while adding ARO as a reportable segment for the new combined company. We also concluded that the

63



activities associated with our arrangements with ARO, consisting of our Transition Services Agreement, Rig Lease Agreements and Secondment Agreement, do not constitute reportable segments and are therefore included within Other in the following segment disclosures. Substantially all of the expenses incurred associated with our Transition Services Agreement are included in general and administrative under "Reconciling Items" in the table set forth below.

General and administrative expense and depreciation expense incurred by our corporate office are not allocated to our operating segments for purposes of measuring segment operating income (loss) and are included in "Reconciling Items." The full operating results included below for ARO (representing only results of ARO from the Transaction Date) are not included within our consolidated results and thus deducted under "Reconciling Items" and replaced with our equity in earnings of ARO. See Note 4 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information on ARO and related arrangements.

Segment information for each of the years in the three-year period ended December 31, 2019 is presented below (in millions). 
 
Year Ended December 31, 2019
 
Floaters
 
Jackups
 
ARO
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,014.4

 
$
834.6

 
$
410.5

 
$
204.2

 
$
(410.5
)
 
$
2,053.2

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
  Contract drilling
  (exclusive of depreciation)
898.6

 
788.9

 
280.2

 
118.5

 
(280.2
)
 
1,806.0

  Loss on impairment
88.2

 
10.2

 

 

 
5.6

 
104.0

  Depreciation
378.6

 
212.4

 
40.3

 

 
(21.6
)
 
609.7

  General and administrative

 

 
27.1

 

 
161.8

 
188.9

Equity in earnings of ARO

 

 

 

 
(12.6
)
 
(12.6
)
Operating income (loss)
$
(351.0
)
 
$
(176.9
)
 
$
62.9

 
$
85.7

 
$
(288.7
)
 
$
(668.0
)
 
Year Ended December 31, 2018
 
Floaters
 
Jackups
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,013.5

 
$
630.9

 
$
61.0

 
$

 
$
1,705.4

Operating expenses
 
 
 
 
 
 
 
 
 
  Contract drilling
  (exclusive of depreciation)
737.4

 
526.5

 
55.5

 

 
1,319.4

  Loss on impairment

 
40.3

 

 

 
40.3

  Depreciation
311.8

 
153.3

 

 
13.8

 
478.9

  General and administrative

 

 

 
102.7

 
102.7

Operating income (loss)
$
(35.7
)
 
$
(89.2
)
 
$
5.5

 
$
(116.5
)
 
$
(235.9
)


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Year Ended December 31, 2017
 
Floaters
 
Jackups
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,143.5

 
$
640.3

 
$
59.2

 
$

 
$
1,843.0

Operating expenses
 
 
 
 
 
 
 
 
 
  Contract drilling
  (exclusive of depreciation)
624.2

 
512.1

 
53.2

 

 
1,189.5

  Loss on impairment
174.7

 
8.2

 

 

 
182.9

  Depreciation
297.4

 
131.5

 

 
15.9

 
444.8

  General and administrative

 

 

 
157.8

 
157.8

Operating income (loss)
$
47.2

 
$
(11.5
)
 
$
6.0

 
$
(173.7
)
 
$
(132.0
)

Floaters

During 2019, revenues were consistent with the prior year. The $109.3 million of revenue earned by the Rowan rigs and $41.0 million due to the commencement of VALARIS DS-9 drilling operations were offset by the sale of VALARIS 5006 and ENSCO 6001, fewer days under contract and lower average day rates across the remaining floater fleet.

Contract drilling expense increased by $161.2 million, or 22%, as compared to the prior year primarily due to $142.4 million of contract drilling expense incurred by the Rowan rigs and $38.2 million due to the commencement of VALARIS DS-9 drilling operations. The increase was partially offset by the sale of VALARIS 5006 and ENSCO 6001 and lower costs on idle rigs.

Depreciation expense increased by $66.8 million, or 21%, compared to the prior year primarily due to the addition of the Rowan rigs to the fleet and commencement of VALARIS DS-9 drilling operations.

During 2018, revenues declined by $130.0 million, or 11%, as compared to the prior year primarily due to lower average day rates resulting from the expiration of above-market, older contracts that were replaced with new market-rate contracts and sale of ENSCO 6001. The decline was partially offset by the addition of Atwood rigs to the fleet and commencement of VALARIS DS-10 drilling operations.

Contract drilling expense increased by $113.2 million, or 18%, as compared to the prior year primarily due to the addition of Atwood rigs to the fleet and commencement of VALARIS DS-10 drilling operations. This increase was partially offset by the sale of ENSCO 6001, lower rig reactivation costs and costs incurred in the prior year to settle a previously disclosed legal contingency.

Depreciation expense increased by $14.4 million, or 5%, compared to the prior year primarily due to the addition of Atwood rigs and commencement of VALARIS DS-10 drilling operations. The increase was partially offset by lower depreciation expense on non-core assets that were impaired to scrap value during the fourth quarter of 2017.

Jackups
    
During 2019, revenues increased by $203.7 million, or 32%, as compared to the prior year primarily due to $212.9 million of revenue earned by the Rowan rigs and $43.1 million due to the commencement of VALARIS JU-123, VALARIS JU-140 and VALARIS JU-141 drilling operations. This increase was partially offset by the sale of ENSCO 97 and ENSCO 80, which operated in the prior-year period.

Contract drilling expense increased by $262.4 million, or 50%, as compared to the prior year primarily due to $208.8 million of contract drilling expense incurred by the Rowan rigs and $31.3 million due to the commencement

65



of drilling operations for VALARIS JU-123, VALARIS JU-140 and VALARIS JU-141. This increase was partially offset by the sale of ENSCO 97 and ENSCO 80.

Depreciation expense increased by $59.1 million, or 39%, as compared to the prior year primarily due to the addition of Rowan rigs to the fleet and the commencement of VALARIS JU-123 drilling operations.
    
During 2018, revenues declined by $9.4 million, or 1%, as compared to the prior year primarily due to the sale of ENSCO 52 and ENSCO 80 and lower average day rates across the fleet. These declines were partially offset by more days under contract across the fleet, the commencement of VALARIS JU-140 and VALARIS JU-141 contracts and the addition of Atwood rigs to the fleet.

Contract drilling expense increased by $14.4 million, or 3%, as compared to the prior year primarily due to more days under contract across the fleet, the addition of Atwood rigs and contract commencements for VALARIS JU-140 and VALARIS JU-141. These increases were partially offset by lower rig reactivation costs and the sale of ENSCO 52 and ENSCO 80.

Depreciation expense increased by $21.8 million, or 17%, as compared to the prior year primarily due to the addition of Atwood rigs and VALARIS JU-140 and VALARIS JU-141 to the fleet. The increase was partially offset by lower depreciation expense on a non-core rig that was impaired to scrap value during the fourth quarter of 2017.

ARO

ARO currently owns a fleet of seven jackup rigs, leases another nine jackup rigs from us and plans to purchase up to 20 newbuild jackup rigs over an approximate 10 year period. In January 2020, ARO ordered the first two newbuild jackups with delivery scheduled in 2022. The rigs we lease to ARO are done so through bareboat charter agreements whereby substantially all operating costs are incurred by ARO. All nine jackup rigs leased to ARO are under three-year contracts with Saudi Aramco. All seven ARO-owned jackup rigs are under long-term contracts with Saudi Aramco.

The operating revenues of ARO reflect revenues earned under drilling contracts with Saudi Aramco for the seven ARO-own jackup rigs and the nine rigs leased from us that operated during the period from the Transaction Date through December 31, 2019.

The contract drilling, depreciation and general and administrative expenses are also for the period from the Transaction Date through December 31, 2019. Contract drilling expenses are inclusive of the bareboat charter fees for the rigs leased from us and costs incurred under the Secondment Agreement. General and administrative expenses include costs incurred under the Transition Services Agreement and other administrative costs.

Other

Other revenues increased $143.2 million, or 235%, for the year ended December 31, 2019, as compared to the prior year period, primarily due to revenues earned from our rigs leased to ARO, revenues earned under the Secondment Agreement and Transition Services Agreement of $58.2 million, $49.9 million and $17.3 million, respectively.

Other contract drilling expenses increased $63.0 million, or 114%, for the year ended December 31, 2019, respectively, as compared to the prior year period, primarily due to costs incurred for services provided to ARO under the Secondment Agreement and other costs for ARO rigs.
    
Impairment of Long-Lived Assets

See Note 6 and Note 14 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on impairment of long-lived assets.
    

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Other Income (Expense), Net
 
The following table summarizes other income (expense), net, for each of the years in the three-year period ended December 31, 2019 (in millions):
 
2019
 
2018
 
2017
Interest income
$
28.1

 
$
14.5

 
$
25.8

Interest expense, net:
 
 
 
 
 
Interest expense
(449.2
)
 
(345.3
)
 
(296.7
)
Capitalized interest
20.9

 
62.6

 
72.5

 
(428.3
)
 
(282.7
)

(224.2
)
Other, net
1,004.4

 
(34.8
)
 
134.4

 
$
604.2

 
$
(303.0
)

$
(64.0
)
 
Interest income increased during 2019 as compared to the respective prior year period primarily due to interest income of $16.8 million earned on the shareholder note from ARO (see Note 4 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on ARO) acquired in the Rowan Transaction. Interest income declined during 2018 as compared to the respective prior-year period as a result of a decrease in our average short-term investment balances.

Interest expense increased during 2019 by $103.9 million, or 30%, as compared to the prior year due to interest expense incurred on Rowan's senior notes. Interest expense increased during 2018 by $48.6 million, or 16%, as compared to the prior year due to debt transactions we undertook during the first quarter of 2018 (see Note 7 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on debt).

Interest expense capitalized declined during 2019 and 2018 by $41.7 million, or 67%, and $9.9 million, or 14%, as compared to the prior year periods, due to a decline in the amount of capital invested in newbuild construction resulting from newbuild rigs being placed into service.

Other, net, during 2019 included a gain on bargain purchase recognized in connection with the Rowan Transaction of $637.0 million, a pre-tax gain related to the settlement award from the SHI matter of $200.0 million discussed in Note 13 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" and a pre-tax gain from debt extinguishment of $194.1 million related to the senior notes repurchased in connection with our July 2019 tender offers. This increase was partially offset by settlement of a Middle East dispute discussed in Note 13 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" as well as foreign currency losses as discussed below.
    
Our functional currency is the U.S. dollar, and a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than the U.S. dollar. These transactions are remeasured in U.S. dollars based on a combination of both current and historical exchange rates. Net foreign currency exchange losses, inclusive of offsetting fair value derivatives, were $7.4 million, $17.2 million and $5.1 million, and were included in other, net, in our consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017, respectively. Net foreign currency exchange losses incurred during 2019 included $3.3 million and $2.8 million, related to euros and Angolan kwanza, respectively. Net foreign currency exchange losses incurred during 2018 included $5.8 million, $3.6 million and $2.0 million, related to Angolan kwanza, euros and Brazilian reals, respectively. During 2017, the net foreign currency exchange losses incurred were $2.1 million, $1.9 million and $1.0 million, related to euros, Indonesian rupiahs and Brazilian reals, respectively.

Net unrealized gains of $5.0 million, unrealized losses of $0.7 million and unrealized gains of $4.5 million from marketable securities held in our supplemental executive retirement plans ("the SERP") were included in other,

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net, in our consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017, respectively. Information on the fair value measurement of our marketable securities held in the SERP is presented in Note 5 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data."
    
Provision for Income Taxes
 
Valaris plc, our parent company, is domiciled and resident in the U.K. Our subsidiaries conduct operations and earn income in numerous countries and are subject to the laws of taxing jurisdictions within those countries. The income of our non-U.K. subsidiaries is generally not subject to U.K. taxation. Income tax rates imposed in the tax jurisdictions in which our subsidiaries conduct operations vary, as does the tax base to which the rates are applied. In some cases, tax rates may be applicable to gross revenues, statutory or negotiated deemed profits or other bases utilized under local tax laws, rather than to net income.

Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. As a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in profitability levels and changes in tax laws, our annual effective income tax rate may vary substantially from one reporting period to another. In periods of declining profitability, our income tax expense may not decline proportionally with income, which could result in higher effective income tax rates. Further, we may continue to incur income tax expense in periods in which we operate at a loss.

U.S. Tax Reform

The U.S. Tax Cuts and Jobs Act (“U.S. tax reform”) was enacted on December 22, 2017 and introduced significant changes to U.S. income tax law, including a reduction in the statutory income tax rate from 35% to 21% effective January 1, 2018, a one-time transition tax on deemed repatriation of deferred foreign income, a base erosion anti-abuse tax that effectively imposes a minimum tax on certain payments to non-U.S. affiliates, new and revised rules relating to the current taxation of certain income of foreign subsidiaries and revised rules associated with limitations on the deduction of interest.

Due to the timing of the enactment of U.S. tax reform and the complexity involved in applying its provisions, we made reasonable estimates of its effects and recorded such amounts in our consolidated financial statements as of December 31, 2017 on a provisional basis. Throughout 2018, we continued to analyze applicable information and data, interpret rules and guidance issued by the U.S. Treasury Department and Internal Revenue Service, and make adjustments to the provisional amounts, as provided for in Staff Accounting Bulletin No. 118. The U.S. Treasury Department continued finalizing rules associated with U.S. tax reform during 2018 and 2019.

During 2019, we recognized a tax expense of $13.8 million associated with final rules issued related to U.S. tax reform. During 2018, we recognized a tax benefit of $11.7 million associated with the one-time transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries. We recognized a net tax expense of $16.5 million during the fourth quarter of 2017 in connection with enactment of U.S. tax reform, consisting of a $38.5 million tax expense associated with the one-time transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries, a $17.3 million tax expense associated with revisions to rules over the taxation of income of foreign subsidiaries, a $20.0 million tax benefit resulting from the re-measurement of our deferred tax assets and liabilities as of December 31, 2017 to reflect the reduced tax rate and a $19.3 million tax benefit resulting from adjustments to the valuation allowance on deferred tax assets.

See Note 12 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information.



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Effective Tax Rate

During the years ended December 31, 2019, 2018 and 2017, we recorded income tax expense of $128.4 million, $89.6 million and $109.2 million, respectively. Our consolidated effective income tax rates were (201.3)%, (16.6)% and (55.7)% during the same periods, respectively.
Our 2019 consolidated effective income tax rate included $2.3 million associated with the impact of various discrete tax items, including $28.3 million of tax expense associated with final rules relating to U.S. tax reform, gains on repurchase of debt and settlement proceeds, partially offset by $26.0 million of tax benefit related to restructuring transactions, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and other resolutions of prior year tax matters and rig sales.

Our 2018 consolidated effective income tax rate includes the impact of various discrete tax items, including $46.0 million of tax benefit associated with the utilization of foreign tax credits subject to a valuation allowance, the transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries, and a restructuring transaction, partially offset by $21.0 million of tax expense related to recovery of certain costs associated with an ongoing legal matter, repurchase and redemption of senior notes and rig sales.

Our 2017 consolidated effective income tax rate included $32.2 million associated with the impact of various discrete tax items, including $16.5 million of tax expense associated with U.S. tax reform and $15.7 million of tax expense associated with the exchange offers and debt repurchases, rig sales, a restructuring transaction, settlement of a previously disclosed legal contingency, the effective settlement of a liability for unrecognized tax benefits associated with a tax position taken in prior years and other resolutions of prior year tax matters.
    
Excluding the impact of the aforementioned discrete tax items, our consolidated effective income tax rates for the years ended December 31, 2019, 2018 and 2017 were (14.6)%, (24.8)% and (96.0)%, respectively. The changes in our consolidated effective income tax rate excluding discrete tax items during the three-year period result primarily from U.S. tax reform and changes in the relative components of our earnings from the various taxing jurisdictions in which our drilling rigs are operated and/or owned and differences in tax rates in such taxing jurisdictions.

Divestitures

Our business strategy has been to focus on ultra-deepwater floater and premium jackup operations and de-emphasize other assets and operations that are not part of our long-term strategic plan or that no longer meet our standards for economic returns. Consistent with this strategy, we sold 12 jackup rigs, two dynamically positioned semisubmersible rigs and two moored semisubmersible rigs during the three-year period ended December 31, 2019.

We continue to focus on our fleet management strategy in light of the composition of our rig fleet. As part of this strategy, we may act opportunistically from time to time to monetize assets to enhance shareholder value and improve our liquidity profile, in addition to selling or disposing of older, lower-specification or non-core rigs.

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We sold the following rigs during the three-year period ended December 31, 2019 (in millions):
Rig
 
Date of Sale
 
Classification(1)
 
Segment(1)
 
Net Proceeds
 
Net Book Value(2)
 
Pre-tax Gain/(Loss)
VALARIS JU-96
 
December 2019
 
Continuing
 
Jackups
 
$
1.9

 
$
.3

 
$
1.6

VALARIS 5006
 
November 2019
 
Continuing
 
Floaters
 
7.0

 
6.0

 
1.0

VALARIS JU-42
 
October 2019
 
Continuing
 
Jackups
 
2.9

 
2.5

 
.4

Gorilla IV
 
May 2019
 
Continuing
 
Jackups
 
2.5

 
2.5

 

ENSCO 97
 
April 2019
 
Continuing
 
Jackups
 
1.7

 
1.0

 
.7

ENSCO 80
 
August 2018
 
Continuing
 
Jackups
 
1.0

 
.5

 
.5

ENSCO 5005
 
August 2018
 
Continuing
 
Floaters
 
4.0

 
2.0

 
2.0

ENSCO 6001
 
July 2018
 
Continuing
 
Floaters
 
2.0

 
.9

 
1.1

ENSCO 7500
 
April 2018
 
Discontinued
 
Floaters
 
2.6

 
1.5

 
1.1

ENSCO 81
 
April 2018
 
Continuing
 
Jackups
 
1.0

 
.3

 
.7

ENSCO 82
 
April 2018
 
Continuing
 
Jackups
 
1.0

 
.3

 
.7

ENSCO 52
 
August 2017
 
Continuing
 
Jackups
 
.8

 
.4

 
.4

ENSCO 86
 
June 2017
 
Continuing
 
Jackups
 
.3

 
.3

 

ENSCO 90
 
June 2017
 
Discontinued
 
Jackups
 
.3

 
.3

 

ENSCO 99
 
June 2017
 
Continuing
 
Jackups
 
.3

 
.3

 

ENSCO 56
 
April 2017
 
Continuing
 
Jackups
 
1.0

 
.3

 
.7

 
 
 
 
 
 
 
 
$
30.3

 
$
19.4


$
10.9


(1) 
Classification denotes the location of the operating results and gain (loss) on sale for each rig in our consolidated statements of operations. For rigs' operating results that were reclassified to discontinued operations in our consolidated statements of operations, these results were previously included within the specified operating segment.
(2) 
Includes the rig's net book value as well as materials and supplies and other assets on the date of the sale.

LIQUIDITY AND CAPITAL RESOURCES
 
We proactively manage our capital structure in an effort to most effectively execute our strategic priorities and maximize value for shareholders. In support of these objectives, we are focused on our liquidity, debt levels and maturity profile and cost of capital. Over the past several years, we have executed a number of financing transactions to improve our financial position and manage our debt maturities, including the July 2019 tender offers discussed below. Based on our balance sheet, our contractual backlog and $1.6 billion of undrawn capacity under our credit facility, we expect to fund our liquidity needs, including expected negative operating cash flows, contractual obligations, anticipated capital expenditures, as well as working capital requirements, from cash and funds borrowed under our credit facility or other future financing arrangements, including available shipyard financing options for our two drillships under construction.

Our credit facility is an integral part of our financial flexibility and liquidity. We also may rely on the issuance of debt and/or equity securities in the future to supplement our liquidity needs. In addition, we may seek to extend our maturities and reduce the overall principal amount of our debt through exchange offers or other liability management transactions. We have significant financial flexibility within our capital structure, including the ability to issue debt that would be structurally senior to our currently outstanding debt, on both an unsecured and secured basis, subject to restrictions contained in our existing debt arrangements. Our liability management efforts, if undertaken, may be unsuccessful or may not improve our financial position to the extent anticipated.

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Additionally, as a result of the Rowan Transaction, we acquired the following debt: (1) $201.4 million in aggregate principal amount of 7.875% unsecured senior notes, which was repaid at maturity in August 2019, (2) $620.8 million in aggregate principal amount of 4.875% unsecured senior notes due 2022, (3) $398.1 million in aggregate principal amount of 4.75% unsecured senior notes due 2024, (4) $500.0 million in aggregate principal amount of 7.375% unsecured senior notes due 2025, (5) $400.0 million in aggregate principal amount of 5.4% unsecured senior notes due 2042 and (6) $400.0 million in aggregate principal amount of 5.85% unsecured senior notes due 2044. Upon closing of the Rowan Transaction, we terminated Rowan's outstanding credit facilities.

During the three-year period ended December 31, 2019, our primary sources of cash were $1.4 billion from net maturities of short-term investments, $1.0 billion in proceeds from the issuance of senior notes, and Rowan cash acquired of $931.9 million. Our primary uses of cash during the same period included $2.2 billion for the repurchase and redemption of outstanding debt, $1.2 billion for the construction, enhancement and other improvement of our drilling rigs, including $813.7 million invested in newbuild construction, $871.6 million for the repayment of Atwood debt and $36.2 million for dividend payments.
 
Explanations of our liquidity and capital resources for each of the years in the three-year period ended December 31, 2019 are set forth below.

Cash Flows and Capital Expenditures
 
Our cash flows from operating activities of continuing operations and capital expenditures on continuing operations for each of the years in the three-year period ended December 31, 2019 were as follows (in millions):

 
 
2019
 
2018
 
2017
Net cash provided by (used in) operating activities of continuing operations
 
$
(276.9
)
 
$
(55.7
)
 
$
259.4

Capital expenditures:
 
 

 
 

 
 

New rig construction
 
$
42.8

 
$
341.1

 
$
429.8

Rig enhancements
 
114.9

 
45.2

 
45.1

Minor upgrades and improvements
 
69.3

 
40.4

 
61.8

 
 
$
227.0

 
$
426.7

 
$
536.7

 
During 2019, cash flows from continuing operations declined by $221.2 million as compared to the prior year due primarily to costs incurred related to the Rowan Transaction, interest on the debt assumed in the Rowan Transaction and declining margins. As our remaining above-market contracts expire and utilization increases with the execution of new market-rate contracts, coupled with the potential impact of rig reactivation costs, our operating cash flows will remain negative through at least 2020.

During 2018, cash flows from continuing operations declined by $315.1 million, or 121%, as compared to the prior year due primarily to declining margins and higher cash interest expense due to the debt financing transactions we undertook during the first quarter of 2018.
         
Based on our current projections, excluding integration-related capital expenditures, we expect capital expenditures during 2020 to approximate $160.0 million for newbuild construction, rig enhancement projects and minor upgrades and improvements. Approximately $30 million of our projected capital expenditures is reimbursable by our customers. Depending on market conditions and opportunities, we may reduce our planned expenditures or make additional capital expenditures to upgrade rigs for customer requirements or acquire additional rigs.


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Dividends

Our Board of Directors declared a $0.01 quarterly cash dividend, on a pre-reverse stock split basis, for the first quarter of 2019. Beginning in the second quarter of 2019, our Board of Directors determined that we will not pay a regular quarterly cash dividend. The declaration and amount of future dividends is at the discretion of our Board of Directors and could change in future periods.

Our revolving credit facility prohibits us from paying dividends in excess of $0.01 per share per fiscal quarter. Dividends in excess of this amount would require the amendment or waiver of such provision.

Financing and Capital Resources

Debt to Capital

Our total debt, total capital and total debt to total capital ratios as of December 31, 2019, 2018 and 2017 are summarized below (in millions, except percentages):
 
2019
 
2018
 
2017
Total debt (1)
$
6,528.1

 
$
5,161.0

 
$
4,882.8

Total capital(2)
$
15,839.0

 
$
13,252.4

 
$
13,614.9

Total debt to total capital
41.2
%
 
38.9
%
 
35.9
%

(1)Total debt consists of the principal amount outstanding.
(2)Total capital consists of total debt and Valaris shareholders' equity.

During 2019, our total debt principal increased by $1.4 billion and total capital increased by $2.6 billion as a result of debt acquired and equity issued in connection with the Rowan Transaction (see Note 3 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data").

During 2018, our total debt increased by $278.2 million and total capital declined by $362.5 million. Our total debt increased as a result of the debt transactions we undertook during the first quarter of 2018 (see Note 7 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data") and our total capital declined as a result of our net loss incurred in that period, partially offset by the aforementioned increase in our total debt.

Convertible Senior Notes

In December 2016, Ensco Jersey Finance Limited, a wholly-owned subsidiary of Valaris plc, issued $849.5 million aggregate principal amount of unsecured 2024 Convertible Notes (the "2024 Convertible Notes") in a private offering. The 2024 Convertible Notes are fully and unconditionally guaranteed, on a senior, unsecured basis, by Valaris plc and are exchangeable into cash, our Class A ordinary shares or a combination thereof, at our election. Interest on the 2024 Convertible Notes is payable semiannually on January 31 and July 31 of each year. The 2024 Convertible Notes will mature on January 31, 2024, unless exchanged, redeemed or repurchased in accordance with their terms prior to such date. Holders may exchange their 2024 Convertible Notes at their option any time prior to July 31, 2023 only under certain circumstances set forth in the indenture governing the 2024 Convertible Notes. On or after July 31, 2023, holders may exchange their 2024 Convertible Notes at any time. The exchange rate is 17.8336 shares per $1,000 principal amount of notes, representing an exchange price of $56.08 per share, and is subject to adjustment upon certain events. The 2024 Convertible Notes may not be redeemed by us except in the event of certain tax law changes.

The indenture governing the 2024 Convertible Notes contains customary events of default, including failure to pay principal or interest on such notes when due, among others. The indenture also contains certain restrictions,

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including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions. See Note 7 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information on our 2024 Convertible Notes.

Senior Notes

As a result of the Rowan Transaction, we acquired the following debt issued by Rowan Companies, Inc. ("RCI") and guaranteed by Rowan: (1) $201.4 million in aggregate principal amount of 7.875% unsecured senior notes due 2019, which was repaid at maturity in August 2019, (2) $620.8 million in aggregate principal amount of 4.875% unsecured senior notes due 2022 (the "Rowan 2022 Notes"), (3) $398.1 million in aggregate principal amount of 4.75% unsecured senior notes due 2024 (the "Rowan 2024 Notes"), (4) $500.0 million in aggregate principal amount of 7.375% unsecured senior notes due 2025 (the "Rowan 2025 Notes"), (5) $400.0 million in aggregate principal amount of 5.4% unsecured senior notes due 2042 (the "Rowan 2042 Notes") and (6) $400.0 million in aggregate principal amount of 5.85% unsecured senior notes due 2044 (the "Rowan 2044 Notes" and collectively, the "Rowan Notes"). Upon closing of the Rowan Transaction, we terminated Rowan's outstanding credit facilities. On February 3, 2020, Rowan and RCI transferred substantially all their assets on a consolidated basis to Valaris plc, Valaris plc became the obligor on the notes and Rowan and RCI were relieved of their obligations under the notes and the related indenture.

On January 26, 2018, we issued $1.0 billion aggregate principal amount of unsecured 7.75% senior notes due 2026 at par, net of $16.5 million in debt issuance costs. Interest on the 2026 Notes is payable semiannually on February 1 and August 1 of each year.

During 2017, we exchanged $332.0 million aggregate principal amount of unsecured 8.00% senior notes due 2024 (the “8% 2024 Notes”) for certain amounts of our outstanding senior notes due 2019, 2020 and 2021. Interest on the 8% 2024 Notes is payable semiannually on January 31 and July 31 of each year.

During 2015, we issued $700.0 million aggregate principal amount of unsecured 5.20% senior notes due 2025 (the “2025 Notes”) at a discount of $2.6 million and $400.0 million aggregate principal amount of unsecured 5.75% senior notes due 2044 (the “New 2044 Notes”) at a discount of $18.7 million in a public offering. Interest on the 2025 Notes is payable semiannually on March 15 and September 15 of each year. Interest on the New 2044 Notes is payable semiannually on April 1 and October 1 of each year.

During 2014, we issued $625.0 million aggregate principal amount of unsecured 4.50% senior notes due 2024 (the "2024 Notes") at a discount of $0.9 million and $625.0 million aggregate principal amount of unsecured 5.75% senior notes due 2044 (the "Existing 2044 Notes") at a discount of $2.8 million. Interest on the 2024 Notes and the Existing 2044 Notes is payable semiannually on April 1 and October 1 of each year. The Existing 2044 Notes together with the New 2044 Notes, the "2044 Notes", are treated as a single series of debt securities under the indenture governing the notes.

During 2011, we issued $1.5 billion aggregate principal amount of unsecured 4.70% senior notes due 2021 (the “2021 Notes”) at a discount of $29.6 million in a public offering. Interest on the 2021 Notes is payable semiannually on March 15 and September 15 of each year.

Upon consummation of our acquisition of Pride International LLC ("Pride") during 2011, we assumed outstanding debt comprised of $900.0 million aggregate principal amount of unsecured 6.875% senior notes due 2020$500.0 million aggregate principal amount of unsecured 8.5% senior notes due 2019 and $300.0 million aggregate principal amount of unsecured 7.875% senior notes due 2040 (collectively, the "Acquired Notes" and together with the Rowan Notes, 2021 Notes, 8% 2024 Notes, 2024 Notes, 2025 Notes, 2026 Notes and 2044 Notes, the "Senior Notes").  Valaris plc has fully and unconditionally guaranteed the performance of all Pride obligations with respect to the Acquired Notes.  See "Note 17 - Guarantee of Registered Securities" included in "Item 8. Financial Statements and Supplementary Data" for additional information on the guarantee of the Acquired Notes.
   

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We may redeem the Senior Notes in whole at any time, or in part from time to time, prior to maturity. If we elect to redeem the Rowan 2022 Notes, Rowan 2024 Notes, 8% 2024 Notes, 2024 Notes, 2025 Notes, Rowan 2025 Notes and 2026 Notes before the date that is three months prior to the maturity date or the Rowan 2042 Notes, Rowan 2044 Notes and 2044 Notes before the date that is six months prior to the maturity date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued and unpaid interest and a "make-whole" premium. If we elect to redeem these notes on or after the aforementioned dates, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued and unpaid interest, but we are not required to pay a "make-whole" premium.

We may redeem each series of the 2021 Notes and the Acquired Notes, in whole or in part, at any time at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a "make-whole" premium.

The indentures governing the Senior Notes contain customary events of default, including failure to pay principal or interest on such notes when due, among others. The indentures governing the Senior Notes also contain certain restrictions, including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions.

Debentures Due 2027

During 1997, Ensco International Incorporated issued $150.0 million of unsecured 7.20% Debentures due 2027 (the "Debentures"). Interest on the Debentures is payable semiannually on May 15 and November 15 of each year. We may redeem the Debentures, in whole or in part, at any time prior to maturity, at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a "make-whole" premium. During 2009, Valaris plc entered into a supplemental indenture to unconditionally guarantee the principal and interest payments on the Debentures. See "Note 17 - Guarantee of Registered Securities" included in "Item 8. Financial Statements and Supplementary Data" for additional information on the guarantee of the Debentures.

The Debentures and the indenture pursuant to which the Debentures were issued also contain customary events of default, including failure to pay principal or interest on the Debentures when due, among others. The indenture also contains certain restrictions, including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions.

 Tender Offers and Open Market Repurchases

On June 25, 2019, we commenced cash tender offers for certain series of senior notes issued by us and Ensco International Incorporated and RCI, our wholly-owned subsidiaries. The tender offers expired on July 23, 2019, and we repurchased $951.8 million of our outstanding senior notes for an aggregate purchase price of $724.1 million. As a result of the transaction, we recognized a pre-tax gain from debt extinguishment of $194.1 million, net of discounts, premiums and debt issuance costs.

Concurrent with the issuance of the 2026 Notes in January 2018, we launched cash tender offers for up to $985.0 million aggregate principal amount of certain series of senior notes issued by us and Pride, our wholly-owned subsidiary, and as a result we repurchased $595.4 million of our senior notes. Subsequently, we issued a redemption notice for the remaining principal amount of the $55.0 million principal amount of the 8.50% senior notes due 2019 and repurchased $71.4 million principal amount of our senior notes due 2020. As a result of these transactions, we recognized a pre-tax loss from debt extinguishment of $19.0 million, net of discounts, premiums, debt issuance costs and commissions.

During 2017, we repurchased $194.1 million of our outstanding senior notes on the open market for an aggregate purchase price of $204.5 million with cash on hand and recognized an insignificant pre-tax loss, net of discounts, premiums and debt issuance costs.

74




Our tender offers and open market repurchases during the three-year period ended December 31, 2019 are summarized in the following table (in millions):

 
Aggregate Principal Amount Repurchased
 
Aggregate Repurchase Price(1)
Year Ended December 31, 2019
 
 
 
4.50% Senior notes due 2024
$
320.0

 
$
240.0

4.75% Senior notes due 2024
79.5

 
61.2

8.00% Senior notes due 2024
39.7

 
33.8

5.20% Senior notes due 2025
335.5

 
250.0

7.375% Senior notes due 2025
139.2

 
109.2

7.20% Senior notes due 2027
37.9

 
29.9

 
$
951.8

 
$
724.1

Year Ended December 31, 2018
 
 
 
8.50% Senior notes due 2019
$
237.6

 
$
256.8

6.875% Senior notes due 2020
328.0

 
354.7

4.70% Senior notes due 2021
156.2

 
159.7

 
$
721.8

 
$
771.2

Year Ended December 31, 2017
 
 
 
8.50% Senior notes due 2019
$
54.6

 
$
60.1

6.875% Senior notes due 2020
100.1

 
105.1

4.70% Senior notes due 2021
39.4

 
39.3

 
$
194.1

 
$
204.5


(1)    Excludes accrued interest paid to holders of the repurchased senior notes.

Exchange Offers

During 2017, we completed exchange offers to exchange our outstanding 2019, 2020 and 2021 notes for the 8% 2024 Notes and cash. The exchange offers resulted in the tender of $649.5 million aggregate principal amount of our outstanding notes that were settled and exchanged as follows (in millions):
 
Aggregate Principal Amount Repurchased
 
8% Senior Notes Due 2024 Consideration
 
Cash
Consideration
 
Total Consideration
8.50% Senior notes due 2019
$
145.8

 
$
81.6

 
$
81.7

 
$
163.3

6.875% Senior notes due 2020
129.8

 
69.3

 
69.4

 
138.7

4.70% Senior notes due 2021
373.9

 
181.1

 
181.4

 
362.5

 
$
649.5

 
$
332.0

 
$
332.5

 
$
664.5


During the year ended December 31, 2017, we recognized a pre-tax loss on the exchange offers of approximately $6.2 million.


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Revolving Credit    

Effective upon closing of the Rowan Transaction, we amended our credit facility to, among other changes, increase the borrowing capacity. Previously, our credit facility had a borrowing capacity of $2.0 billion through September 2019 that declined to $1.3 billion through September 2020 and $1.2 billion through September 2022. Subsequent to the amendment, our borrowing capacity was $1.7 billion through September 2022. Following the amendment, our borrowing capacity was reduced by $75 million to $1.6 billion. The reduction occurred after we became aware that a signatory for a purported lender was not an authorized representative of that lender and therefore concluded the $75 million was not binding. The credit agreement governing the credit facility includes an accordion feature allowing us to increase the future commitments by up to an aggregate amount not to exceed $250.0 million.

Advances under the credit facility bear interest at Base Rate or LIBOR plus an applicable margin rate, depending on our credit ratings. We are required to pay a quarterly commitment fee on the undrawn portion of the $1.6 billion commitment, which is also based on our credit ratings.

On December 6, 2019, Moody's downgraded our corporate family rating from B3 to Caa1 and our senior unsecured notes from Caa1 to Caa2. Previously, in September 2019, Standard & Poor's downgraded our senior unsecured bonds from B to B- and our issuer rating from B- to CCC+. The rating actions did not impact the interest rates applicable to our borrowings and the quarterly commitment fee on the undrawn portion of the $1.6 billion commitment. The applicable margin rates are 3.25% per annum for Base Rate advances and 4.25% per annum for LIBOR advances. The quarterly commitment fee is 0.75% per annum on the undrawn portion of the $1.6 billion commitment.

The credit facility requires us to maintain a total debt to total capitalization ratio that is less than or equal to 60% and to provide guarantees from certain of our rig-owning subsidiaries sufficient to meet certain guarantee coverage ratios. The credit facility also contains customary restrictive covenants, including, among others, prohibitions on creating, incurring or assuming certain debt and liens (subject to customary exceptions, including a permitted lien basket that permits us to raise secured debt up to the lesser of $1 billion or 10% of consolidated tangible net worth (as defined in the credit facility)); entering into certain merger arrangements; selling, leasing, transferring or otherwise disposing of all or substantially all of our assets; making a material change in the nature of the business; paying or distributing dividends on our ordinary shares (subject to certain exceptions, including the ability to pay a quarterly dividend of $0.01 per share); borrowings, if after giving effect to any such borrowings and the application of the proceeds thereof, the aggregate amount of available cash (as defined in the credit facility) would exceed $200 million; and entering into certain transactions with affiliates.

The credit facility also includes a covenant restricting our ability to repay indebtedness maturing after September 2022, which is the final maturity date of our credit facility. This covenant is subject to certain exceptions that permit us to manage our balance sheet, including the ability to make repayments of indebtedness (i) of acquired companies within 90 days of the completion of the acquisition or (ii) if, after giving effect to such repayments, available cash is greater than $250 million and there are no amounts outstanding under the credit facility.

As of December 31, 2019, we were in compliance in all material respects with our covenants under the credit facility. We expect to remain in compliance with our credit facility covenants during 2020. We had no amounts outstanding under the credit facility as of December 31, 2019 and 2018. As of January 31, 2020, we had $90 million of total outstanding borrowings under our credit facility.

Our access to credit and capital markets is limited because of our credit rating. Our current credit ratings, and any additional actual or anticipated downgrades in our corporate credit ratings or the credit rating of our notes will limit our ability to access credit and capital markets, or to restructure or refinance our indebtedness. In addition, future financings or refinancings will result in higher borrowing costs and may require collateral and/or more restrictive terms and covenants, which may further restrict our operations. Limitations on our ability to access credit and capital markets could have a material adverse impact on our financial position, operating results or cash flows.


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Maturities

The descriptions of our senior notes above reflect the original principal amounts issued, which have subsequently changed as a result of our tenders, repurchases, exchanges, redemptions and new debt issuances such that the maturities of our debt at December 31, 2019 were as follows (in millions):
Senior Notes
Original Principal
 
2016 Tenders, Repurchases and Equity Exchange
 
2017 Exchange Offers and Repurchases
 
2018 Tender Offers, Redemption
 
2019 Tender Offers and Acquired Debt
 
Remaining Principal
6.875% due 2020
$
900.0

 
$
(219.2
)
 
$
(229.9
)
 
$
(328.0
)
 
$

 
$
122.9

4.70% due 2021
1,500.0

 
(817.0
)
 
(413.3
)
 
(156.2
)
 

 
113.5

4.875% due 2022 (1)

 

 

 

 
620.8

 
620.8

3.00% Exchangeable senior notes due 2024
849.5

 

 

 

 

 
849.5

4.50% due 2024
625.0

 
(1.7
)
 

 

 
(320.0
)
 
303.3

4.75% due 2024 (1)

 

 

 

 
318.6

 
318.6

8.00% due 2024

 

 
332.0

 

 
(39.7
)
 
292.3

5.20% due 2025
700.0

 
(30.7
)
 

 

 
(335.5
)
 
333.8

7.375% due 2025 (1)

 

 

 

 
360.8

 
360.8

7.75% due 2026

 

 

 
1,000.0

 

 
1,000.0

7.20% due 2027
150.0

 

 

 

 
(37.9
)
 
112.1

7.875% due 2040
300.0

 

 

 

 
 
 
300.0

5.40% due 2042 (1)

 

 

 

 
400.0

 
400.0

5.75% due 2044
1,025.0

 
(24.5
)
 

 

 

 
1,000.5

5.85% due 2044 (1)

 

 

 

 
400.0

 
400.0

Total
$
6,549.5

 
$
(1,155.1
)
 
$
(511.6
)
 
$
278.2

 
$
1,367.1

 
$
6,528.1


(1) These senior notes were acquired in the Rowan Transaction.

Other Financing Arrangements

We filed an automatically effective shelf registration statement on Form S-3 with the U.S. Securities and Exchange Commission on November 21, 2017, which provides us the ability to issue debt securities, equity securities, guarantees and/or units of securities in one or more offerings. The registration statement expires in November 2020.

During 2018, our shareholders approved our current share repurchase program. Subject to certain provisions under English law, including the requirement of the Company to have sufficient distributable reserves, we may repurchase shares up to a maximum of $500 million in the aggregate from one or more financial intermediaries under the program, but in no case more than 16.3 million shares. The program terminates in May 2023. As of December 31, 2019, there had been no share repurchases under this program. Our credit facility prohibits us from repurchasing our shares, except in certain limited circumstances. Any share repurchases, outside of such limited circumstances, would require the amendment or waiver of such provision.

From time to time, we and our affiliates may repurchase our outstanding senior notes in the open market, in privately negotiated transactions, through tender offers, exchange offers or otherwise, or we may redeem senior notes, pursuant to their terms. In connection with any exchange, we may issue equity, issue new debt (including debt that is structurally senior to our existing senior notes) and/or pay cash consideration. Any future repurchases, exchanges or redemptions will depend on various factors existing at that time. There can be no assurance as to which, if any, of these alternatives (or combinations thereof) we may choose to pursue in the future or, if any such alternatives are pursued, that they will be successful. There can be no assurance that an active trading market will exist for our outstanding senior notes following any such transaction.

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Investment in ARO and Notes Receivable from ARO

    We consider our investment in ARO to be a significant component of our investment portfolio and an integral part of our long-term capital resources. We expect to receive cash from ARO in the future both from the maturity of our long-term notes receivable and from the distribution of earnings from ARO. The long-term notes receivable earn interest at LIBOR plus two percent and mature during 2027 and 2028.

The distribution of earnings to the joint-venture partners is at the discretion of the ARO Board of Managers, consisting of 50/50 membership of managers appointed by Saudi Aramco and managers appointed by us, with approval required by both shareholders. The timing and amount of any cash distributions to the joint-venture partners cannot be predicted with certainty and will be influenced by various factors, including the liquidity position and long-term capital requirements of ARO. ARO has not made a cash distribution of earnings to its partners since its formation. See Note 4 included in "Item 8. Financial Statements and Supplementary Data" for additional information on our investment in ARO and notes receivable from ARO.

The following table summarizes the maturity schedule of our notes receivable from ARO as of December 31, 2019 (in millions):
Maturity Date
Principal amount
October 2027
$
275.2

October 2028
177.7

Total
$
452.9


Contractual Obligations

We have various contractual commitments related to our new rig construction and rig enhancement agreements, long-term debt and operating leases. We expect to fund these commitments from existing cash and short-term investments and funds borrowed under our credit facility or other future financing arrangements, including available shipyard financing options for our two drillships under construction.  The actual timing of our new rig construction and rig enhancement payments may vary based on the completion of various milestones, which are beyond our control.  The following table summarizes our significant contractual obligations as of December 31, 2019 and the periods in which such obligations are due (in millions):
 
Payments due by period
 
2020
 
2021 and 2022
 
2023 and 2024
 
Thereafter
 
Total
Principal payments on long-term debt
$
122.9

 
$
734.3

 
$
1,763.7

 
$
3,907.2

 
$
6,528.1

Interest payments on long-term debt
377.4

 
714.8

 
634.7

 
2,536.1

 
4,263.0

New rig construction agreements(1) (2)

 
248.9

 

 

 
248.9

Operating leases
25.4

 
31.0

 
18.8

 
17.2

 
92.4

Total contractual obligations(3)
$
525.7

 
$
1,729.0

 
$
2,417.2

 
$
6,460.5

 
$
11,132.4

 
(1)During 2019, we entered into amendments to our construction agreements with the shipyard for VALARIS DS-13 and VALARIS DS-14 to provide for, among other things, two-year extensions of the delivery date of each rig in exchange for payment of all accrued holding costs through March 31, 2019, totaling approximately $23 million. The new delivery dates for the VALARIS DS-13 and VALARIS DS-14 are September 30, 2021 and June 30, 2022, respectively. We can elect to request earlier delivery in certain circumstances. The interest rate on the final milestone payments increased from 5% to 7% per annum from October 1, 2019, for the VALARIS DS-13, and from July 1, 2020, for the VALARIS DS-14, until the actual delivery dates. The final milestone payments and applicable interest are due at the new delivery dates (or, if accelerated, the actual delivery dates) and are estimated to be approximately $313.3 million in aggregate for both rigs, inclusive of interest, assuming we take delivery on the new delivery date. In lieu

78



of making the final milestone payments, we have the option to take delivery of the rigs and issue a promissory note for each rig to the shipyard owner for the amount due. If we issue the promissory note to the shipyard owner, we would also be required to provide a guarantee from Valaris plc.

(2)Total commitments are based on fixed-price shipyard construction contracts, exclusive of our internal costs associated with project management, commissioning and systems integration testing. Total commitments also exclude holding costs and interest.
a

(3)Contractual obligations do not include $323.1 million of unrecognized tax benefits, inclusive of interest and penalties, included on our consolidated balance sheet as of December 31, 2019.  We are unable to specify with certainty the future periods in which we may be obligated to settle such amounts. In addition, we have a potential obligation to fund ARO for newbuild jackup rigs. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. See Note 3 and Note 4 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data." for additional information on the Rowan Transaction and our joint venture with ARO, respectively.

Other Commitments

We have other commitments that we are contractually obligated to fulfill with cash under certain circumstances.  These commitments include letters of credit to guarantee our performance as it relates to our drilling contracts, contract bidding, customs duties, tax appeals and other obligations in various jurisdictions. Obligations under these letters of credit are not normally called, as we typically comply with the underlying performance requirement. As of December 31, 2019, we had not been required to make collateral deposits with respect to these agreements. The following table summarizes our other commitments as of December 31, 2019 (in millions):
 
Commitment expiration by period
 
2020
 
2021 and 2022
 
2023 and 2024
 
Thereafter
 
Total
Letters of credit
$
82.7

 
$
10.6

 
$

 
$
6.2

 
$
99.5


Liquidity
 
Our liquidity position as of December 31, 2019, 2018 and 2017 is summarized below (in millions, except ratios):
 
2019
 
2018
 
2017
Cash and cash equivalents
$
97.2

 
$
275.1

 
$
445.4

Short-term investments

 
329.0

 
440.0

Available credit facility borrowing capacity
1,622.2

 
2,000.0

 
2,000.0

Total liquidity
$
1,719.4

 
$
2,604.1

 
$
2,885.4

Working capital
$
233.7

 
$
781.2

 
$
853.5

Current ratio
1.3

 
2.5

 
2.1


We expect to fund our liquidity needs, including contractual obligations and anticipated capital expenditures, as well as working capital requirements, from our cash, and funds borrowed under our credit facility or future financing arrangements, including available shipyard financing options for our two drillships under construction. We may rely on the issuance of debt and/or equity securities in the future to supplement our liquidity needs. As of December 31, 2019, we had no amounts drawn under our credit facility and $1.6 billion in remaining borrowing capacity.


79



Our credit facility is an integral part of our financial flexibility and liquidity. We also may rely on the issuance of debt and/or equity securities in the future to supplement our liquidity needs. In addition, we may seek to extend our maturities and reduce the overall principal amount of our debt through exchange offers or other liability management transactions. We have significant financial flexibility within our capital structure, including the ability to issue debt that would be structurally senior to our currently outstanding debt, on both an unsecured and secured basis, subject to restrictions contained in our existing debt arrangements. Our liability management efforts, if undertaken, may be unsuccessful or may not improve our financial position to the extent anticipated.

Our ability to maintain a sufficient level of liquidity to meet our financial obligations will also be dependent upon our future performance, which will be subject to general economic conditions, industry cycles and financial, business and other factors affecting our operations, many of which are beyond our control. For example, if we experience further deterioration in demand for offshore drilling, our ability to maintain a sufficient level of liquidity could be materially and adversely impacted, which could have a material adverse impact on our business, financial condition, results of operations, cash flows and our ability to repay or refinance our debt.

Our access to credit and capital markets is limited because of our credit rating. Our current credit ratings, and any additional actual or anticipated downgrades in our corporate credit ratings or the credit rating of our notes will limit our ability to access credit and capital markets, or to restructure or refinance our indebtedness. In addition, future financings or refinancings will result in higher borrowing costs and may require collateral and/or more restrictive terms and covenants, which may further restrict our operations. Limitations on our ability to access credit and capital markets could have a material adverse impact on our financial position, operating results or cash flows.

Recent Tax Assessments

    During 2019, we received income tax assessments totaling approximately €142.0 million (approximately $159.0 million converted using the current period-end exchange rates) and A$101 million (approximately $70.9 million converted at current period-end exchange rates) from taxing authorities in Luxembourg and Australia, respectively. We are contesting these assessments and have filed applications for appeal. During the third quarter of 2019, we made a A$42 million payment (approximately $29 million at then-current exchange rates) to the Australian tax authorities to litigate the assessment. We may make a payment to the Luxembourg tax authorities in advance of the final resolution of these assessments. Although the outcome of such assessments cannot be predicted with certainty, unfavorable outcomes could have a material adverse effect on our liquidity. We have recorded a $119.0 million liability for these assessments as of December 31, 2019. See Note 12 included in "Item 8. Financial Statements and Supplementary Data" for additional information on recent tax assessments.

Effects of Climate Change and Climate Change Regulation
 
Greenhouse gas (“GHG”) emissions have increasingly become the subject of international, national, regional, state and local attention. At the December 2015 Conference of the Parties to the United Nations Framework Convention on Climate Change held in Paris, an agreement was reached that requires countries to review and “represent a progression” in their intended nationally determined contributions to the reduction of GHG emissions, setting GHG emission reduction goals every five years beginning in 2020. This agreement, known as the Paris Agreement, entered into force on November 4, 2016 and, as of February 2019, had been ratified by 187 of the 197 parties to the United Nations Framework Convention on Climate Change, including the United Kingdom, the United States and the majority of the other countries in which we operate. However, in 2019, the United States formally initiated the process of withdrawing from participation in the Paris Agreement, with such withdrawal taking place no earlier than November 4, 2020. In response to the announced withdrawal plan, a number of state and local governments in the United States have expressed intentions to take GHG-related actions by implementing their own programs to reduce GHG emissions. The United Nations Climate Change Conference held in Katowice, Poland in December 2018 adopted further rules regarding the implementation of the Paris Agreement and, in connection with this conference, numerous countries issued commitments to increase their GHG emission reduction targets.
    

80



In an effort to reduce GHG emissions, governments have implemented or considered legislative and regulatory mechanisms to institute carbon pricing mechanisms, such as the European Union’s Emission Trading System, and to impose technical requirements to reduce carbon emissions. The Companies Act 2006 (Strategic and Directors' Reports) Regulations 2013 now requires all quoted U.K. companies, including Valaris plc, to report their annual GHG emissions in the Company's directors' report.

During 2009, the United States Environmental Protection Agency (the “EPA”) officially published its findings that emissions of carbon dioxide, methane and other GHGs present an endangerment to human health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. These findings allowed the agency to proceed with the adoption and implementation of regulations to restrict GHG emissions under existing provisions of the Clean Air Act that establish permitting requirements, including emissions control technology requirements, for certain large stationary sources that are potential major sources of GHG emissions. These requirements for stationary sources took effect on January 2, 2011; however, in June 2014 the U.S. Supreme Court reversed a D.C. Circuit Court of Appeals decision upholding these rules and struck down the EPA’s greenhouse gas permitting rules to the extent they impose a requirement to obtain a federal air permit based solely on emissions of greenhouse gases. Large sources of other air pollutants, such as VOC or nitrogen oxides, could still be required to implement process or technology controls and obtain permits regarding emissions of greenhouse gases. The EPA has also adopted rules requiring annual monitoring and reporting of GHG emissions from specified sources in the U.S., including, among others, certain onshore and offshore oil and natural gas production facilities. Although a number of bills related to climate change have been introduced in the U.S. Congress in the past, comprehensive federal climate legislation has not yet been passed by Congress. If such legislation were to be adopted in the U.S., such legislation could adversely impact many industries. In the absence of federal legislation, almost half of the states have begun to address GHG emissions, primarily through the development or planned development of emission inventories or regional GHG cap and trade programs.

Future regulation of GHG emissions could occur pursuant to future treaty obligations, statutory or regulatory changes or new climate change legislation in the jurisdictions in which we operate. Depending on the particular program, we, or our customers, could be required to control GHG emissions or to purchase and surrender allowances for GHG emissions resulting from our operations. It is uncertain whether any of these initiatives will be implemented. If such initiatives are implemented, we do not believe that such initiatives would have a direct, material adverse effect on our financial condition, operating results and cash flows in a manner different than our competitors.

Restrictions on GHG emissions or other related legislative or regulatory enactments could have an indirect effect in those industries that use significant amounts of petroleum products, which could potentially result in a reduction in demand for petroleum products and, consequently, our offshore contract drilling services. We are currently unable to predict the manner or extent of any such effect. Furthermore, one of the long-term physical effects of climate change may be an increase in the severity and frequency of adverse weather conditions, such as hurricanes, which may increase our insurance costs or risk retention, limit insurance availability or reduce the areas in which, or the number of days during which, our customers would contract for our drilling rigs in general and in the Gulf of Mexico in particular. We are currently unable to predict the manner or extent of any such effect.

In addition, there have also been efforts in recent years to influence the investment community, including investment advisors and certain sovereign wealth, pension and endowment funds promoting divestment of fossil fuel equities and pressuring lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Such environmental activism and initiatives aimed at limiting climate change and reducing air pollution could ultimately interfere with our business activities and operations. Finally, increasing attention to the risks of climate change has resulted in an increased possibility of lawsuits brought by public and private entities against oil and gas companies in connection with their greenhouse gas emissions. Should we be targeted by any such litigation, we may incur liability, which, to the extent that societal pressures or political or other factors are involved, could be imposed without regard to the company’s causation of or contribution to the asserted damage, or to other mitigating factors.


81



MARKET RISK
 
We use derivatives to reduce our exposure to foreign currency exchange rate risk. Our functional currency is the U.S. dollar. As is customary in the oil and gas industry, a majority of our revenues and expenses are denominated in U.S. dollars; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than the U.S. dollar. We maintain a foreign currency exchange rate risk management strategy that utilizes derivatives to reduce our exposure to unanticipated fluctuations in earnings and cash flows caused by changes in foreign currency exchange rates.

We utilize cash flow hedges to hedge forecasted foreign currency denominated transactions, primarily to reduce our exposure to foreign currency exchange rate risk on future expected contract drilling expenses and capital expenditures denominated in various foreign currencies. We predominantly structure our drilling contracts in U.S. dollars, which significantly reduces the portion of our cash flows and assets denominated in foreign currencies. As of December 31, 2019, we had cash flow hedges outstanding to exchange an aggregate $199.1 million for various foreign currencies.

We have net assets and liabilities denominated in numerous foreign currencies and use various strategies to manage our exposure to changes in foreign currency exchange rates. We occasionally enter into derivatives that hedge the fair value of recognized foreign currency denominated assets or liabilities, thereby reducing exposure to earnings fluctuations caused by changes in foreign currency exchange rates. We do not designate such derivatives as hedging instruments. In these situations, a natural hedging relationship generally exists whereby changes in the fair value of the derivatives offset changes in the carrying value of the underlying hedged items. As of December 31, 2019, we held derivatives not designated as hedging instruments to exchange an aggregate $47.1 million for various foreign currencies.
 
If we were to incur a hypothetical 10% adverse change in foreign currency exchange rates, net unrealized losses associated with our foreign currency denominated assets and liabilities as of December 31, 2019 would approximate $27.1 million. Approximately $1.6 million of these unrealized losses would be offset by corresponding gains on the derivatives utilized to offset changes in the fair value of net assets and liabilities denominated in foreign currencies.

We utilize derivatives and undertake foreign currency exchange rate hedging activities in accordance with our established policies for the management of market risk. We mitigate our credit risk relating to counterparties of our derivatives through a variety of techniques, including transacting with multiple, high-quality financial institutions, thereby limiting our exposure to individual counterparties and by entering into International Swaps and Derivatives Association, Inc. (“ISDA”) Master Agreements, which include provisions for a legally enforceable master netting agreement, with our derivative counterparties. The terms of the ISDA agreements may also include credit support requirements, cross default provisions, termination events or set-off provisions. Legally enforceable master netting agreements reduce credit risk by providing protection in bankruptcy in certain circumstances and generally permitting the closeout and netting of transactions with the same counterparty upon the occurrence of certain events.

We do not enter into derivatives for trading or other speculative purposes. We believe that our use of derivatives and related hedging activities reduces our exposure to foreign currency exchange rate risk and does not expose us to material credit risk or any other material market risk. All our derivatives mature during the next 18 months. See Note 8 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information on our derivative instruments.


82



CRITICAL ACCOUNTING POLICIES AND ESTIMATES
 
The preparation of financial statements and related disclosures in conformity with accounting principles generally accepted in the United States of America requires us to make estimates, judgments and assumptions that affect the amounts reported in our consolidated financial statements and accompanying notes. Our significant accounting policies are included in Note 1 to our consolidated financial statements. These policies, along with our underlying judgments and assumptions made in their application, have a significant impact on our consolidated financial statements. We identify our critical accounting policies as those that are the most pervasive and important to the portrayal of our financial position and operating results and that require the most difficult, subjective and/or complex judgments regarding estimates in matters that are inherently uncertain. Our critical accounting policies are those related to property and equipment, impairment of long-lived assets, income taxes and pensions.
 
Property and Equipment

As of December 31, 2019, the carrying value of our property and equipment totaled $15.1 billion, which represented 89% of total assets.  This carrying value reflects the application of our property and equipment accounting policies, which incorporate our estimates, judgments and assumptions relative to the capitalized costs, useful lives and salvage values of our rigs.
 
We develop and apply property and equipment accounting policies that are designed to appropriately and consistently capitalize those costs incurred to enhance, improve and extend the useful lives of our assets and expense those costs incurred to repair or maintain the existing condition or useful lives of our assets. The development and application of such policies requires estimates, judgments and assumptions relative to the nature of, and benefits from, expenditures on our assets. We establish property and equipment accounting policies that are designed to depreciate our assets over their estimated useful lives. The judgments and assumptions used in determining the useful lives of our property and equipment reflect both historical experience and expectations regarding future operations, utilization and performance of our assets. The use of different estimates, judgments and assumptions in the establishment of our property and equipment accounting policies, especially those involving the useful lives of our rigs, would likely result in materially different asset carrying values and operating results.
 
The useful lives of our drilling rigs are difficult to estimate due to a variety of factors, including technological advances that impact the methods or cost of oil and natural gas exploration and development, changes in market or economic conditions and changes in laws or regulations affecting the drilling industry. We evaluate the remaining useful lives of our rigs on a periodic basis, considering operating condition, functional capability and market and economic factors.

Property and equipment held-for-sale is recorded at the lower of net book value or fair value less cost to sell.

During 2019, we recorded a pre-tax, non-cash loss on impairment of $98.4 million related to one floater and one jackup rig, both of which are older, less capable, non-core assets in our fleet. We estimate the aforementioned impairment will cause a decline in depreciation expense of approximately $8.6 million for the year ended December 31, 2020.
            
Our fleet of 24 floater rigs, excluding two rigs under construction, represented 64% of the gross cost and 63% of the net carrying amount of our depreciable property and equipment as of December 31, 2019.  Our floater rigs are depreciated over useful lives ranging from 10 to 35 years.  Our fleet of 50 jackup rigs, represented 31% of both the gross cost and of the net carrying amount of our depreciable property and equipment as of December 31, 2019.  Our jackup rigs are depreciated over useful lives ranging from 10 to 30 years.


83



The following table provides an analysis of estimated increases and decreases in depreciation expense from continuing operations that would have been recognized for the year ended December 31, 2019 for various assumed changes in the useful lives of our drilling rigs effective January 1, 2019:

Increase (decrease) in
useful lives of our
drilling rigs
 
Estimated (decrease) increase in
depreciation expense that would
have been recognized (in millions)
10%
 
$(50.8)
20%
 
(93.2)
(10%)
 
61.9
(20%)
 
138.6
    
Impairment of Property and Equipment

We recorded pre-tax, non-cash losses on impairment of long-lived assets of $98.4 million, $40.3 million and $182.9 million during 2019, 2018 and 2017, respectively. See Note 6 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for additional information on our property and equipment.
        
We evaluate the carrying value of our property and equipment, primarily our drilling rigs, when events or changes in circumstances indicate that the carrying value of such rigs may not be recoverable. Generally, extended periods of idle time and/or inability to contract rigs at economical rates are an indication that a rig may be impaired. Impairment situations may arise with respect to specific individual rigs, groups of rigs, such as a specific type of drilling rig, or rigs in a certain geographic location.

For property and equipment used in our operations, recoverability generally is determined by comparing the carrying value of an asset to the expected undiscounted future cash flows of the asset. If the carrying value of an asset is not recoverable, the amount of impairment loss is measured as the difference between the carrying value of the asset and its estimated fair value. The determination of expected undiscounted cash flow amounts requires significant estimates, judgments and assumptions, including utilization levels, day rates, expense levels and capital requirements, as well as cash flows generated upon disposition, for each of our drilling rigs. Due to the inherent uncertainties associated with these estimates, we perform sensitivity analysis on key assumptions as part of our recoverability test.

Our judgments and assumptions about future cash flows to be generated by our drilling rigs are highly subjective and based on consideration of the following:

global macroeconomic and political environment,
historical utilization, day rate and operating expense trends by asset class,
regulatory requirements such as surveys, inspections and recertification of our rigs,
remaining useful lives of our rigs,
expectations on the use and eventual disposition of our rigs,
weighted-average cost of capital,
oil price projections,
sanctioned and unsanctioned offshore project data,
offshore economic project break-even data,
global rig supply and construction orders,
global rig fleet capabilities and relative rankings, and
expectations of global rig fleet attrition.


84



We collect and analyze the above information to develop a range of estimated utilization levels, day rates, expense levels and capital requirements, as well as estimated cash flows generated upon disposition. The most subjective assumptions that impact our impairment analyses include projections of future oil prices and timing of global rig fleet attrition, which, in large part, impact our estimates on timing and magnitude of recovery from the current industry downturn. However, there are numerous judgments and assumptions unique to the projected future cash flows of each rig that individually, and in the aggregate, can significantly impact the recoverability of its carrying value.

The highly cyclical nature of our industry cannot be reasonably predicted with a high level of accuracy and, therefore, differences between our historical judgments and assumptions and actual results will occur. We reassess our judgments and assumptions in the period in which significant differences are observed and may conclude that a triggering event has occurred and perform a recoverability test. We recognized impairment charges in recent periods upon observation of significant unexpected changes in our business climate and estimated useful lives of certain assets.

There are numerous factors underlying the highly cyclical nature of our industry that are reasonably likely to impact our judgments and assumptions including, but not limited to, the following:

changes in global economic conditions,
production levels of the Organization of Petroleum Exporting Countries (“OPEC”),
production levels of non-OPEC countries,
advances in exploration and development technology,
offshore and onshore project break-even economics,
development and exploitation of alternative fuels,
natural disasters or other operational hazards,
changes in relevant law and governmental regulations,
political instability and/or escalation of military actions in the areas we operate,
changes in the timing and rate of global newbuild rig construction, and
changes in the timing and rate of global rig fleet attrition.

There is a wide range of interrelated changes in our judgments and assumptions that could reasonably occur as a result of unexpected developments in the aforementioned factors, which could result in materially different carrying values for an individual rig, group of rigs or our entire rig fleet, materially impacting our operating results.

Income Taxes
 
We conduct operations and earn income in numerous countries and are subject to the laws of numerous tax jurisdictions.  As of December 31, 2019, our consolidated balance sheet included a $72.4 million net deferred income tax liability, a $45.6 million liability for income taxes currently payable and a $323.1 million liability for unrecognized tax benefits, inclusive of interest and penalties.

The carrying values of deferred income tax assets and liabilities reflect the application of our income tax accounting policies and are based on estimates, judgments and assumptions regarding future operating results and levels of taxable income. Carryforwards and tax credits are assessed for realization as a reduction of future taxable income by using a more-likely-than-not determination. We do not offset deferred tax assets and deferred tax liabilities attributable to different tax paying jurisdictions.

We do not provide deferred taxes on the undistributed earnings of certain subsidiaries because our policy and intention is to reinvest such earnings indefinitely. Should we make a distribution from these subsidiaries in the form of dividends or otherwise, we may be subject to additional income taxes.

The carrying values of liabilities for income taxes currently payable and unrecognized tax benefits are based on our interpretation of applicable tax laws and incorporate estimates, judgments and assumptions regarding the use of tax planning strategies in various taxing jurisdictions. The use of different estimates, judgments and assumptions

85



in connection with accounting for income taxes, especially those involving the deployment of tax planning strategies, may result in materially different carrying values of income tax assets and liabilities and operating results.

We operate in several jurisdictions where tax laws relating to the offshore drilling industry are not well developed. In jurisdictions where available statutory law and regulations are incomplete or underdeveloped, we obtain professional guidance and consider existing industry practices before utilizing tax planning strategies and meeting our tax obligations.

Tax returns are routinely subject to audit in most jurisdictions and tax liabilities occasionally are finalized through a negotiation process. In some jurisdictions, income tax payments may be required before a final income tax obligation is determined in order to avoid significant penalties and/or interest. While we historically have not experienced significant adjustments to previously recognized tax assets and liabilities as a result of finalizing tax returns, there can be no assurance that significant adjustments will not arise in the future. In addition, there are several factors that could cause the future level of uncertainty relating to our tax liabilities to increase, including the following:

During recent years, the number of tax jurisdictions in which we conduct operations has increased, and we currently anticipate that this trend will continue.

In order to utilize tax planning strategies and conduct operations efficiently, our subsidiaries frequently enter into transactions with affiliates that are generally subject to complex tax regulations and are frequently reviewed and challenged by tax authorities.

We may conduct future operations in certain tax jurisdictions where tax laws are not well developed, and it may be difficult to secure adequate professional guidance.

Tax laws, regulations, agreements, treaties and the administrative practices and precedents of tax authorities change frequently, requiring us to modify existing tax strategies to conform to such changes.

Pension and Other Postretirement Benefits

Our pension and other postretirement benefit liabilities and costs are based upon actuarial computations that reflect our assumptions about future events, including long-term asset returns, interest rates, annual compensation increases, mortality rates and other factors. Key assumptions at December 31, 2019, included (i) a weighted average discount rate of 3.16% to determine pension benefit obligations, (ii) a weighted average discount rate of 3.82% to determine net periodic pension cost and (iii), an expected long-term rate of return on pension plan assets of 6.48%. The assumed discount rate is based upon the average yield for Moody’s Aa-rated corporate bonds, and the rate of return assumption reflects a probability distribution of expected long-term returns that is weighted based upon plan asset allocations. A one-percentage-point decrease in the assumed discount rate would increase our recorded pension and other postretirement benefit liabilities by approximately $108.8 million, while a one-percentage-point decrease (increase) in the expected long-term rate of return on plan assets would increase (decrease) annual net benefits cost by approximately $4.0 million. To develop the expected long-term rate of return on assets assumption, we considered the current level of expected returns on risk-free investments (primarily government bonds), the historical level of the risk premium associated with the plans’ other asset classes, and the expectations for future returns of each asset class. The expected return for each asset class was then weighted based upon the current asset allocation to develop the expected long-term rate of return on assets assumption for the plan, which was 6.48% at December 31, 2019.


NEW ACCOUNTING PRONOUNCEMENTS

See Note 1 to our consolidated financial statements included in "Item 8. Financial Statements and Supplementary Data" for information on new accounting pronouncements.


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Item 7A.  Quantitative and Qualitative Disclosures About Market Risk

Information required under Item 7A. has been incorporated into "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk."


Item 8.  Financial Statements and Supplementary Data

MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) or 15d-15(f). Our internal control over financial reporting system is designed to provide reasonable assurance as to the reliability of our financial reporting and the preparation and presentation of consolidated financial statements in accordance with accounting principles generally accepted in the United States, as well as to safeguard assets from unauthorized use or disposition. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, we have conducted an evaluation of the effectiveness of our internal control over financial reporting based on the criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, we have concluded that our internal control over financial reporting is effective as of December 31, 2019 to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

Management's assessment of the effectiveness of the Company's internal control over financial reporting as of December 31, 2019 excluded Rowan Companies plc internal control over financial reporting associated with total revenue of $135.0 million and total expenses of $259.0 million included in the consolidated financial statements of Valaris plc and subsidiaries for the year ended December 31, 2019.

KPMG LLP, the independent registered public accounting firm who audited our consolidated financial statements, has issued an audit report on our internal control over financial reporting. KPMG LLP's audit report on our internal control over financial reporting is included herein.
 

February 21, 2020

87



REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 

To the Board of Directors and Shareholders
Valaris plc:
 
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of Valaris plc and subsidiaries (the Company) as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive loss, and cash flows for each of the years in the three‑year period ended December 31, 2019 and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the years in the three‑year period ended December 31, 2019, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 21, 2020 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the 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 Matters
The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate 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 matters 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 matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Assessment of the valuation of property and equipment and investment in joint venture acquired in the Rowan Transaction
As discussed in Notes 1 and 3 to the consolidated financial statements, the Company merged with Rowan Companies plc on April 11, 2019 (the Rowan Transaction). In connection with the Rowan Transaction, the assets acquired and liabilities assumed were recorded at their estimated fair value at the acquisition date. The key assumptions used to estimate the acquisition-date fair values of the acquired property and equipment and investment were forecasted day rates, forecasted utilization and risk-adjusted discount rates. The Company, with the use of a third-

88



party valuation expert, estimated the fair value of the assets acquired and liabilities assumed at $4.8 billion and $2.8 billion, respectively.
We identified the evaluation of the Company's valuation of property and equipment and investment in joint venture acquired in the Rowan Transaction as a critical audit matter. The use of unobservable inputs and subjective assumptions necessary to estimate the fair value of those assets required a high degree of subjective auditor judgment to evaluate the assumptions described above. In addition, the discounted cash flow model included the internally-developed assumptions described above for which there were limited observable market information, and the calculated fair value of such assets was sensitive to possible changes to these assumptions.
The primary procedures we performed to address this critical audit matter included the following. We tested certain internal controls over the Company’s acquisition-date valuation process, including controls over the development of the relevant assumptions listed above. We evaluated the Company’s forecasted day rates and utilization by comparing them to historical information, data from the Company’s peers and industry reports. We challenged the Company's information and assumptions based on evidence we identified that was contrary to that used by the Company. In addition, we involved valuation professionals with specialized skills and knowledge, who assisted in evaluating the Company’s discount rates by comparing the Company's discount rates against discount rate ranges that we independently developed using publicly available market data for comparable entities.
Assessment of property and equipment impairment triggering events
As discussed in Notes 1 and 6 to the consolidated financial statements, the net carrying value of property and equipment as of December 31, 2019 was $15.1 billion. The Company evaluates the carrying value of property and equipment for impairment, on a quarterly basis, by identifying events or changes in circumstances, including global macroeconomic conditions, that indicate the carrying value may not be recoverable (triggering events). Generally, extended periods of idle time or the inability to contract rigs at economical rates are an indication that a rig may be impaired.
We identified the assessment of property and equipment impairment triggering events as a critical audit matter. The Company's evaluation of possible triggering events uses both internal and external data, including the following key indicators and internally-developed assumptions: historical utilization trends, oil price projections and global rig supply and demand trends. Assessing these indicators and assumptions requires a high degree of subjective auditor judgment to perform procedures and evaluate the audit evidence obtained.
The primary procedures we performed to address this critical audit matter included the following. We tested certain internal controls over the Company's identification of possible property and equipment impairment triggering events, including controls to develop the indicators and assumptions listed above. We evaluated the information used by the Company in its triggering event assessment by comparing such information to historical information, external third-party expectations, peer company results, and other industry data.
Assessment of income tax positions pertaining to certain transactions
As discussed in Notes 1 and 12 to the consolidated financial statements, the Company evaluates the income tax effect of certain transactions which often require local country tax expertise and judgment. This requires the Company to interpret complex tax laws in multiple jurisdictions to assess if its tax positions have a more than 50 percent likelihood of being sustained with the taxing authorities.
We identified the assessment of income tax positions pertaining to certain transactions as a critical audit matter. Complex auditor judgment was required to: (1) evaluate the Company's assessment that the tax position has a more than 50 percent likelihood of being sustained with the taxing authorities; and (2) evaluate the Company's measurement of the tax effects resulting from these transactions. In addition, specialized skills were required to evaluate the Company's interpretation of tax laws in the applicable jurisdictions.
The primary procedures we performed to address this critical audit matter included the following. We tested certain internal controls over the Company's income tax process, including controls related to the interpretation of tax laws applicable to certain transactions, assessment that tax positions pertaining to those transactions have a more

89



than 50 percent likelihood of being sustained with taxing authorities and measurement of the tax effects resulting from those transactions. We involved tax professionals with specialized skills and knowledge, who assisted in reading the Company's documentation and evaluating the Company's interpretation of local tax laws, assessing the likelihood that the tax position has a greater than 50 percent likelihood of being sustained with taxing authorities, and measuring the tax effects resulting from those transactions.
/s/ KPMG LLP

We have served as the Company’s auditor since 2002.
Houston, Texas
February 21, 2020



90



REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM


To the Board of Directors and Shareholders
Valaris plc:

Opinion on Internal Control Over Financial Reporting
We have audited Valaris plc and subsidiaries’ (the Company) internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive loss, and cash flows for each of the years in the three-year period ended December 31, 2019, and the related notes (collectively, the consolidated financial statements), and our report dated February 21, 2020 expressed an unqualified opinion on those consolidated financial statements.
The Company acquired Rowan Companies plc during 2019, and management excluded from its assessment of the effectiveness of the Company's internal controls over financial reporting as of December 31, 2019, Rowan Companies plc's internal control over financial reporting associated with total revenue of $135.0 million and total expenses of $259.0 million included in the consolidated financial statements of the Company for the year ended December 31, 2019. Our audit of internal control over financial reporting of the Company also excluded an evaluation of the internal control over financial reporting of Rowan Companies plc.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely

91



detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 /s/ KPMG LLP
Houston, Texas
February 21, 2020

92



VALARIS PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(in millions, except per share amounts)
 
  Year Ended December 31,    
 
2019
 
2018
 
2017
OPERATING REVENUES
$
2,053.2

 
$
1,705.4

 
$
1,843.0

OPERATING EXPENSES
 

 
 

 
 

Contract drilling (exclusive of depreciation)
1,806.0

 
1,319.4

 
1,189.5

Loss on impairment
104.0

 
40.3

 
182.9

Depreciation
609.7

 
478.9

 
444.8

General and administrative
188.9

 
102.7

 
157.8

 
2,708.6

 
1,941.3

 
1,975.0

EQUITY IN EARNINGS OF ARO
(12.6
)
 

 

OPERATING LOSS
(668.0
)

(235.9
)

(132.0
)
OTHER INCOME (EXPENSE)
 

 
 

 
 

Interest income
28.1

 
14.5

 
25.8

Interest expense, net
(428.3
)
 
(282.7
)
 
(224.2
)
Other, net
1,004.4

 
(34.8
)
 
134.4

 
604.2

 
(303.0
)
 
(64.0
)
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
(63.8
)
 
(538.9
)
 
(196.0
)
PROVISION FOR INCOME TAXES
 

 
 

 
 

Current income tax expense
104.5

 
33.0

 
54.2

Deferred income tax expense
23.9

 
56.6

 
55.0

 
128.4

 
89.6

 
109.2

LOSS FROM CONTINUING OPERATIONS
(192.2
)

(628.5
)

(305.2
)
INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET

 
(8.1
)
 
1.0

NET LOSS
(192.2
)
 
(636.6
)
 
(304.2
)
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS
(5.8
)
 
(3.1
)
 
.5

NET LOSS ATTRIBUTABLE TO VALARIS
$
(198.0
)
 
$
(639.7
)

$
(303.7
)
LOSS PER SHARE - BASIC AND DILUTED
 

 
 

 
 

Continuing operations
$
(1.14
)
 
$
(5.82
)
 
$
(3.66
)
Discontinued operations

 
(0.08
)
 

 
$
(1.14
)
 
$
(5.90
)
 
$
(3.66
)
 
 
 
 
 
 
WEIGHTED-AVERAGE SHARES OUTSTANDING
 
 
 
 
 
Basic and Diluted
173.4

 
108.5

 
83.1


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

93



VALARIS PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(in millions)

 
  Year Ended December 31,    
 
2019
 
2018
 
2017
NET LOSS
$
(192.2
)
 
$
(636.6
)
 
$
(304.2
)
OTHER COMPREHENSIVE INCOME (LOSS), NET
 
 
 
 
 
Net changes in pension and other postretirement plan assets and benefit obligations recognized in other comprehensive loss, net of income tax benefits of ($5.9 million) for the year ended December 31, 2019
(21.7
)
 

 

Net change in fair value of derivatives
1.6

 
(9.7
)
 
8.5

Reclassification of net (gains) losses on derivative instruments from other comprehensive income (loss) into net loss
8.3

 
(1.0
)
 
.4

Other
(.2
)
 
(.5
)
 
.7

NET OTHER COMPREHENSIVE INCOME (LOSS)
(12.0
)
 
(11.2
)

9.6

 
 
 
 
 
 
COMPREHENSIVE LOSS
(204.2
)
 
(647.8
)
 
(294.6
)
COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS
(5.8
)
 
(3.1
)
 
.5

COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS
$
(210.0
)
 
$
(650.9
)
 
$
(294.1
)

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



94




VALARIS PLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(in millions, except share and par value amounts)
 
 December 31,
ASSETS
2019
 
2018
CURRENT ASSETS
 
 
 

    Cash and cash equivalents
$
97.2

 
$
275.1

Short-term investments

 
329.0

Accounts receivable, net
520.7

 
344.7

Other
446.5

 
360.9

Total current assets
1,064.4

 
1,309.7

PROPERTY AND EQUIPMENT, AT COST
18,393.8

 
15,517.0

Less accumulated depreciation
3,296.9

 
2,900.8

Property and equipment, net
15,096.9

 
12,616.2

LONG-TERM NOTES RECEIVABLE FROM ARO
452.9

 

INVESTMENT IN ARO
128.7

 

OTHER ASSETS
188.3

 
97.8

 
$
16,931.2

 
$
14,023.7

LIABILITIES AND SHAREHOLDERS' EQUITY
 

 
 

CURRENT LIABILITIES
 

 
 

Accounts payable - trade
$
288.2

 
$
210.5

Accrued liabilities and other
417.7

 
318.0

Current maturities of long-term debt
124.8

 

Total current liabilities
830.7


528.5

LONG-TERM DEBT
5,923.5

 
5,010.4

OTHER LIABILITIES
867.4

 
396.0

COMMITMENTS AND CONTINGENCIES


 


VALARIS SHAREHOLDERS' EQUITY
 

 
 

    Class A ordinary shares, U.S. $.40 par value, 205.9 million and 115.2 million
       shares issued as of December 31, 2019 and 2018
82.4

 
46.1

    Class B ordinary shares, £1 par value, 50,000 shares issued
       as of December 31, 2019 and 2018
.1

 
.1

Additional paid-in capital
8,627.8

 
7,225.0

Retained earnings
671.7

 
874.2

Accumulated other comprehensive income
6.2

 
18.2

Treasury shares, at cost, 7.9 million and 5.9 million shares as of
   December 31, 2019 and 2018
(77.3
)
 
(72.2
)
Total Valaris shareholders' equity
9,310.9

 
8,091.4

NONCONTROLLING INTERESTS
(1.3
)
 
(2.6
)
Total equity
9,309.6

 
8,088.8

 
$
16,931.2

 
$
14,023.7

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

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VALARIS PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in millions)
 
Year Ended December 31,  
 
2019
 
2018
 
2017
OPERATING ACTIVITIES
 

 
 

 
 

Net loss
$
(192.2
)
 
$
(636.6
)
 
$
(304.2
)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities of continuing operations:
 

 
 

 
 

Bargain purchase gain
(637.0
)
 
(1.8
)
 
(140.2
)
Depreciation expense
609.7

 
478.9

 
444.8

(Gain) loss on debt extinguishment
(194.1
)
 
19.0

 
2.6

Loss on impairment
104.0

 
40.3

 
182.9

Share-based compensation expense
37.3

 
29.9

 
34.2

Deferred income tax expense
23.9

 
56.6

 
55.0

Amortization, net
(16.8
)
 
(40.2
)
 
(61.6
)
Equity in earnings of ARO
12.6

 

 

Other
16.8

 
4.5

 
(26.5
)
Changes in operating assets and liabilities, net of acquisition
(27.9
)
 
(6.3
)
 
72.4

Contributions to pension plans and other post-retirement benefits
(13.2
)
 

 

Net cash provided by (used in) operating activities of continuing operations
(276.9
)
 
(55.7
)
 
259.4

INVESTING ACTIVITIES
 

 
 

 
 

Acquisition of Rowan, net of cash acquired
931.9

 

 

Maturities of short-term investments
474.0

 
1,030.0

 
2,042.5

Additions to property and equipment
(227.0
)
 
(426.7
)
 
(536.7
)
Purchases of short-term investments
(145.0
)
 
(919.0
)
 
(1,040.0
)
Net proceeds from disposition of assets
17.7

 
11.0

 
2.8

Acquisition of Atwood, net of cash acquired

 

 
(871.6
)
Net cash provided by (used in) investing activities of continuing operations
1,051.6

 
(304.7
)
 
(403.0
)
FINANCING ACTIVITIES
 

 
 

 
 

Reduction of long-term borrowings
(928.1
)
 
(771.2
)
 
(537.0
)
Borrowings on credit facility
215.0

 

 

Repayments of credit facility borrowings
(215.0
)
 

 

Debt solicitation fees
(9.5
)
 

 

Cash dividends paid
(4.5
)
 
(17.9
)
 
(13.8
)
Proceeds from issuance of senior notes

 
1,000.0

 

Debt issuance costs

 
(17.0
)
 
(12.0
)
Other
(10.2
)
 
(5.7
)
 
(7.7
)
Net cash provided by (used in) financing activities
(952.3
)
 
188.2

 
(570.5
)
Net cash provided by (used in) discontinued operations

 
2.5

 
(.8
)
Effect of exchange rate changes on cash and cash equivalents
(.3
)
 
(.6
)
 
.6

DECREASE IN CASH AND CASH EQUIVALENTS
(177.9
)
 
(170.3
)
 
(714.3
)
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR
275.1

 
445.4

 
1,159.7

CASH AND CASH EQUIVALENTS, END OF YEAR
$
97.2

 
$
275.1

 
$
445.4

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

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VALARIS PLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 
 
1.  DESCRIPTION OF THE BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
    Business
 
We are a leading provider of offshore contract drilling services to the international oil and gas industry. Exclusive of two rigs under construction and one rigs marked for retirement and classified as held-for-sale, we currently own and operate an offshore drilling rig fleet of 74 rigs, with drilling operations in almost every major offshore market across six continents. Inclusive of our rigs under construction, our fleet includes 16 drillships, eight dynamically positioned semisubmersible rigs, two moored semisubmersible rigs and 50 jackup rigs, nine of which are leased to our 50/50 joint venture with Saudi Aramco. We operate the world's largest fleet amongst competitive rigs, including one of the newest ultra-deepwater fleets in the industry and a leading premium jackup fleet.

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 24 countries on six continents. The markets in which we operate include the Gulf of Mexico, Brazil, the Mediterranean, the North Sea, Norway, the Middle East, West Africa, Australia and Southeast Asia.

We provide drilling services on a day rate contract basis. Under day rate contracts, we provide an integrated service that includes the provision of a drilling rig and rig crews for which we receive a daily rate that may vary between the full rate and zero rate throughout the duration of the contractual term, depending on the operations of the rig. We also may receive lump-sum fees or similar compensation for the mobilization, demobilization and capital upgrades of our rigs. 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.

Rowan Transaction

On October 7, 2018, we entered into a transaction agreement (the "Transaction Agreement") with Rowan Companies Limited (formerly Rowan Companies plc ("Rowan")) and on April 11, 2019 (the "Transaction Date"), we completed our combination with Rowan pursuant to the Transaction Agreement (the "Rowan Transaction") and changed our name to Ensco Rowan plc. On July 30, 2019, we changed our name to Valaris plc. Rowan's financial results are included in our consolidated results beginning on the Transaction Date.

As a result of the Rowan Transaction, Rowan shareholders received 2.750 Valaris Class A ordinary shares for each Rowan Class A ordinary share, representing a value of $43.67 per Rowan share based on a closing price of $15.88 per Valaris share on April 10, 2019, the last trading day before the Transaction Date. Total consideration delivered in the Rowan Transaction consisted of 88.3 million Valaris shares with an aggregate value of $1.4 billion. All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split (as defined herein).

Prior to the Rowan Transaction, Rowan and Saudi Aramco formed a 50/50 joint venture to own, manage and operate drilling rigs offshore Saudi Arabia ("Saudi Aramco Rowan Offshore Drilling Company" or "ARO"). ARO currently owns a fleet of seven jackup rigs, leases another nine jackup rigs from us and has plans to purchase up to 20 newbuild jackup rigs over an approximate 10 year period. In January 2020, ARO ordered the first two newbuild jackups scheduled for delivery in 2022. The rigs we lease to ARO are done so through bareboat charter agreements whereby substantially all operating costs are incurred by ARO. All nine jackup rigs leased to ARO are under three-year contracts with Saudi Aramco. All seven ARO-owned jackup rigs are under long-term contracts with Saudi Aramco.

The Rowan Transaction enhanced the market leadership of the combined company with a fleet of high-specification floaters and jackups and positions us well to meet increasing and evolving customer demand. The

97



increased scale, diversification and financial strength of the combined company provides us advantages to better serve our customers. Exclusive of two older jackup rigs marked for retirement, Rowan’s offshore rig fleet at the Transaction Date consisted of four ultra-deepwater drillships and 19 jackup rigs.

Reverse Stock Split

Upon closing of the Rowan Transaction, we effected a consolidation (being a reverse stock split under English law) where every four existing Class A ordinary shares, each with a nominal value of $0.10, were consolidated into one Class A ordinary share, each with a nominal value of $0.40 (the "Reverse Stock Split"). All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split.

Basis of Presentation—U.K. Companies Act 2006 Section 435 Statement

The accompanying consolidated financial statements have been prepared in accordance with U.S. GAAP, which the Board of Directors consider to be the most meaningful presentation of our results of operations and financial position. The accompanying consolidated financial statements do not constitute U.K. statutory accounts for the year ended December 31, 2019 and 2018 as required to be prepared under the U.K. Companies Act 2006.  The U.K. statutory accounts are prepared in accordance with Financial Reporting Standard 102, the financial reporting standard applicable in the U.K. and Republic of Ireland (“FRS 102”).  The auditor has reported on the U.K. statutory accounts for the year ended December 31, 2018; their report was (i) unqualified, (ii) did not include a reference to any matters to which the auditor drew attention by way of emphasis without qualifying their report and (iii) did not contain a statement under section 498 (2) or (3) of the U.K. Companies Act 2006.  The U.K. statutory accounts for the year ended December 31, 2019 have yet to be finalized and will be delivered to the U.K. registrar of companies during 2020.
 
Principles of Consolidation

The accompanying consolidated financial statements include the accounts of Valaris plc, those of our wholly-owned subsidiaries and entities in which we hold a controlling financial interest. All intercompany accounts and transactions have been eliminated. Investments in operating entities in which we have the ability to exercise significant influence, but where we do not control operating and financial policies are accounted for using the equity method. Significant influence generally exists if we have an ownership interest representing between 20% and 50% of the voting stock of the investee. We account for our interest in ARO using the equity method of accounting and only recognize our portion of equity in earnings in our consolidated financial statements. ARO is a variable interest entity; however, we are not the primary beneficiary and therefore do not consolidate ARO.

Pervasiveness of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires us to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities, the related revenues and expenses and disclosures of gain and loss contingencies as of the date of the financial statements. Actual results could differ from those estimates.

Foreign Currency Remeasurement and Translation

Our functional currency is the U.S. dollar. As is customary in the oil and gas industry, a majority of our revenues and expenses are denominated in U.S. dollars; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than the U.S. dollar. These transactions are remeasured in U.S. dollars based on a combination of both current and historical exchange rates. Most transaction gains and losses, including certain gains and losses on our derivative instruments, are included in other, net, in our consolidated statement of operations.  Certain gains and losses from the translation of foreign currency balances of our non-U.S. dollar functional currency subsidiaries are included in accumulated other comprehensive income on our consolidated balance sheet.  Net foreign currency exchange losses, inclusive of offsetting fair value derivatives, were

98



$7.4 million, $17.2 million and $5.1 million, and were included in other, net, in our consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017, respectively.

Cash Equivalents and Short-Term Investments

Highly liquid investments with maturities of three months or less at the date of purchase are considered cash equivalents. Highly liquid investments with maturities of greater than three months but less than one year at the date of purchase are classified as short-term investments.

Short-term investments consisted of time deposits with initial maturities in excess of three months but less than one year and totaled $329.0 million as of December 31, 2018. There were no short-term investments as of December 31, 2019. Cash flows from purchases and maturities of short-term investments were classified as investing activities in our consolidated statements of cash flows for the years ended December 31, 2019, 2018 and 2017. To mitigate our credit risk, our investments in time deposits are diversified across multiple, high-quality financial institutions.
    
Property and Equipment

All costs incurred in connection with the acquisition, construction, major enhancement and improvement of assets are capitalized, including allocations of interest incurred during periods that our drilling rigs are under construction or undergoing major enhancements and improvements. Costs incurred to place an asset into service are capitalized, including costs related to the initial mobilization of a newbuild drilling rig. Repair and maintenance costs are charged to contract drilling expense in the period in which they are incurred. Upon the sale or retirement of assets, the related cost and accumulated depreciation are removed from the balance sheet, and the resulting gain or loss is included in contract drilling expense.

Our property and equipment is depreciated on a straight-line basis, after allowing for salvage values, over the estimated useful lives of our assets. Drilling rigs and related equipment are depreciated over estimated useful lives ranging from four to 35 years. Buildings and improvements are depreciated over estimated useful lives ranging from seven to 30 years. Other equipment, including computer and communications hardware and software costs, is depreciated over estimated useful lives ranging from three to six years.

We evaluate the carrying value of our property and equipment for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For property and equipment used in our operations, recoverability generally is determined by comparing the carrying value of an asset to the expected undiscounted future cash flows of the asset. If the carrying value of an asset is not recoverable, the amount of impairment loss is measured as the difference between the carrying value of the asset and its estimated fair value. Property and equipment held-for-sale is recorded at the lower of net book value or fair value less cost to sell.

We recorded pre-tax, non-cash impairment losses related to long-lived assets of $104.0 million, $40.3 million and $182.9 million during 2019, 2018 and 2017, respectively. See "Note 6 - Property and Equipment" for additional information on our impairment charges.

If the global economy deteriorates and/or our expectations relative to future offshore drilling industry conditions decline, it is reasonably possible that additional impairment charges may occur with respect to specific individual rigs, groups of rigs, such as a specific type of drilling rig, or rigs in a certain geographic location.

Operating Revenues and Expenses    
 
See "Note 2 - Revenue from Contracts with Customers" for information on our accounting policies for revenue recognition and certain operating costs that are deferred and amortized over future periods.
    

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Derivative Instruments

We use derivatives to reduce our exposure to various market risks, primarily foreign currency exchange rate risk. See "Note 8 - Derivative Instruments" for additional information on how and why we use derivatives.

All derivatives are recorded on our consolidated balance sheet at fair value. Derivatives subject to legally enforceable master netting agreements are not offset on our consolidated balance sheet. Accounting for the gains and losses resulting from changes in the fair value of derivatives depends on the use of the derivative and whether it qualifies for hedge accounting. Derivatives qualify for hedge accounting when they are formally designated as hedges and are effective in reducing the risk exposure that they are designated to hedge.

Changes in the fair value of derivatives that are designated as hedges of the variability in expected future cash flows associated with existing recognized assets or liabilities or forecasted transactions ("cash flow hedges") are recorded in accumulated other comprehensive income ("AOCI").  Amounts recorded in AOCI associated with cash flow hedges are subsequently reclassified into contract drilling, depreciation or interest expense as earnings are affected by the underlying hedged forecasted transactions.

Gains and losses on a cash flow hedge, or a portion of a cash flow hedge, that no longer qualifies as effective due to an unanticipated change in the forecasted transaction are recognized currently in earnings and included in other, net, in our consolidated statement of operations based on the change in the fair value of the derivative. When a forecasted transaction becomes probable of not occurring, gains and losses on the derivative previously recorded in AOCI are reclassified currently into earnings and included in other, net, in our consolidated statement of operations.

We occasionally enter into derivatives that hedge the fair value of recognized assets or liabilities but do not designate such derivatives as hedges or the derivatives otherwise do not qualify for hedge accounting. In these situations, a natural hedging relationship generally exists where changes in the fair value of the derivatives offset changes in the fair value of the underlying hedged items. Changes in the fair value of these derivatives are recognized currently in earnings in other, net, in our consolidated statement of operations.

Derivatives with asset fair values are reported in other current assets or other assets, net, on our consolidated balance sheet depending on maturity date. Derivatives with liability fair values are reported in accrued liabilities and other, or other liabilities on our consolidated balance sheet depending on maturity date.

Income Taxes

We conduct operations and earn income in numerous countries. Current income taxes are recognized for the amount of taxes payable or refundable based on the laws and income tax rates in the taxing jurisdictions in which operations are conducted and income is earned.

Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of our assets and liabilities using the enacted tax rates in effect at year-end. A valuation allowance for deferred tax assets is recorded when it is more-likely-than-not that the benefit from the deferred tax asset will not be realized. We do not offset deferred tax assets and deferred tax liabilities attributable to different tax paying jurisdictions.

We operate in certain jurisdictions where tax laws relating to the offshore drilling industry are not well developed and change frequently. Furthermore, we may enter into transactions with affiliates or employ other tax planning strategies that generally are subject to complex tax regulations. As a result of the foregoing, the tax liabilities and assets we recognize in our financial statements may differ from the tax positions taken, or expected to be taken, in our tax returns. Our tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than 50% likely of being realized upon effective settlement with a taxing authority that has full knowledge of all relevant information.

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Interest and penalties relating to income taxes are included in current income tax expense in our consolidated statement of operations.

Our drilling rigs frequently move from one taxing jurisdiction to another based on where they are contracted to perform drilling services. The movement of drilling rigs among taxing jurisdictions may involve a transfer of drilling rig ownership among our subsidiaries through an intercompany rig sale. The pre-tax profit resulting from an intercompany rig sale is eliminated from our consolidated financial statements, and the carrying value of a rig sold in an intercompany transaction remains at historical net depreciated cost prior to the transaction. Our consolidated financial statements do not reflect the asset disposition transaction of the selling subsidiary or the asset acquisition transaction of the acquiring subsidiary. The income tax effects resulting from intercompany rig sales are recognized in earnings in the period in which the sale occurs.

In some instances, we may determine that certain temporary differences will not result in a taxable or deductible amount in future years, as it is more-likely-than-not we will commence operations and depart from a given taxing jurisdiction without such temporary differences being recovered or settled. Under these circumstances, no future tax consequences are expected and no deferred taxes are recognized in connection with such operations. We evaluate these determinations on a periodic basis and, in the event our expectations relative to future tax consequences change, the applicable deferred taxes are recognized or derecognized.

We do not provide deferred taxes on the undistributed earnings of certain subsidiaries because our policy and intention is to reinvest such earnings indefinitely. Should we make a distribution from these subsidiaries in the form of dividends or otherwise, we may be subject to additional income taxes.

The U.S. Tax Cuts and Jobs Act (“U.S. tax reform”) was enacted on December 22, 2017 and introduced significant changes to U.S. income tax law, including a reduction in the statutory income tax rate from 35% to 21% effective January 1, 2018, a one-time transition tax on deemed repatriation of deferred foreign income, a base erosion anti-abuse tax that effectively imposes a minimum tax on certain payments to non-U.S. affiliates, new and revised rules relating to the current taxation of certain income of foreign subsidiaries and revised rules associated with limitations on the deduction of interest. The U.S. Treasury Department issued guidance and continued finalizing rules associated with U.S. tax reform during 2018 and 2019. See "Note 12 - Income Taxes" for additional information.

Share-Based Compensation

We sponsor share-based compensation plans that provide equity compensation to our key employees, officers and non-employee directors. Our Long-Term Incentive Plan (the “2018 LTIP”) allows our Board of Directors to authorize share grants to be settled in cash or shares. Compensation expense for share awards to be settled in shares is measured at fair value on the date of grant and recognized on a straight-line basis over the requisite service period (usually the vesting period). Compensation expense for share awards to be settled in cash is remeasured each quarter with a cumulative adjustment to compensation cost during the period based on changes in our share price. Any adjustments to the compensation cost recognized in our consolidated statement of operations for awards that are forfeited are recognized in the period in which the forfeitures occur. See "Note 10 - Share Based Compensation" for additional information on our share-based compensation.

Pension and Other Post-retirement benefit plans

We measure our actuarially determined obligations and related costs for our defined benefit pension and other post-retirement plans, retiree life and medical supplemental plan benefits, by applying assumptions, the most significant of which include long-term rate of return on plan assets, discount rates and mortality rates. For the long-term rate of return, we develop our assumptions regarding the expected rate of return on plan assets based on historical experience and projected long-term investment returns, and we weight the assumptions based on each plan's asset allocation. For the discount rate, we base our assumptions on a yield curve approach. Actual results may differ from the assumptions included in these calculations. If gains or losses exceed 10% of the greater of the plan assets or plan liabilities, we

101



amortize such gains or losses into income over either the period of expected future service of active participants, or over the expected average remaining lifetime of all participants.
    
Fair Value Measurements

We measure certain of our assets and liabilities based on a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy assigns the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities ("Level 1") and the lowest priority to unobservable inputs ("Level 3").  Level 2 measurements represent inputs that are observable for similar assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1.  See "Note 5 - Fair Value Measurements" for additional information on the fair value measurement of certain of our assets and liabilities.

Noncontrolling Interests

Third parties hold a noncontrolling ownership interest in certain of our non-U.S. subsidiaries. Noncontrolling interests are classified as equity on our consolidated balance sheet, and net income attributable to noncontrolling interests is presented separately in our consolidated statement of operations.  For each of the years in the three-year period ended December 31, 2019, all income attributable to noncontrolling interest was from continuing operations.

Earnings Per Share
    
We compute basic and diluted earnings per share ("EPS") in accordance with the two-class method. Net loss attributable to Valaris used in our computations of basic and diluted EPS is adjusted to exclude net income allocated to non-vested shares granted to our employees and non-employee directors. Weighted-average shares outstanding used in our computation of diluted EPS is calculated using the treasury stock method and includes the effect of all potentially dilutive stock options and excludes non-vested shares. In each of the years in the three-year period ended December 31, 2019, our potentially dilutive instruments were not included in the computation of diluted EPS as the effect of including these shares in the calculation would have been anti-dilutive.
 
The following table is a reconciliation of loss from continuing operations attributable to Valaris shares used in our basic and diluted EPS computations for each of the years in the three-year period ended December 31, 2019 (in millions):

 
2019
 
2018
 
2017
Loss from continuing operations attributable to Valaris
$
(198.0
)
 
$
(631.6
)
 
$
(304.7
)
Income from continuing operations allocated to non-vested share awards
(.1
)
 
(.5
)
 
(.4
)
Loss from continuing operations attributable to Valaris shares
$
(198.1
)
 
$
(632.1
)
 
$
(305.1
)

    
Anti-dilutive share awards totaling 300,000, 1.5 million and 2.0 million for the years ended December 31, 2019, 2018 and 2017, respectively, were excluded from the computation of diluted EPS.
     
We have the option to settle our 3.00% exchangeable senior notes due 2024 (the "2024 Convertible Notes") in cash, shares or a combination thereof for the aggregate amount due upon conversion. See "Note 7 - Debt" for additional information on this issuance. Our intent is to settle the principal amount of the 2024 Convertible Notes in cash upon conversion. If the conversion value exceeds the principal amount (i.e., our share price exceeds the exchange price on the date of conversion), we expect to deliver shares equal to the remainder of our conversion obligation in excess of the principal amount.

During each respective reporting period that our average share price exceeds the exchange price, an assumed number of shares required to settle the conversion obligation in excess of the principal amount will be included in our denominator for the computation of diluted EPS using the treasury stock method. Our average share price did not exceed the exchange price during the years ended December 31, 2019, 2018 and 2017.

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New Accounting Pronouncements

Recently adopted accounting pronouncements

Leases - During 2016, the FASB issued ASU 2016-02, Leases (Topic 842) ("Update 2016-02"), which requires an entity to recognize lease assets and lease liabilities on the balance sheet and to disclose key qualitative and quantitative information about the entity's leasing arrangements. This update is effective for annual and interim periods beginning after December 15, 2018, with early adoption permitted. During our evaluation of Update 2016-02, we concluded that our drilling contracts contain a lease component. In July 2018, the FASB issued Accounting Standard Update 2018-11, Leases (Topic 842), Targeted Improvements, which (1) provided for a new transition method whereby entities could elect to adopt the Update using a prospective with cumulative catch-up approach (the "effective date method") and (2) provided lessors with a practical expedient, by class of underlying asset, to not separate lease and non-lease components and account for the combined component under Topic 606 when the non-lease component is the predominant element of the combined component. The lessor practical expedient is limited to circumstances in which the lease, if accounted for separately, would be classified as an operating lease under Topic 842. We adopted Update 2016-02, effective January 1, 2019, using the effective date method.

With respect to our drilling contracts, which contain a lease component, we elected to apply the practical expedient to not separate the lease and non-lease components and account for the combined component under Topic 606. With respect to all of our drilling contracts that existed on the adoption date, we concluded that the criteria to elect the lessor practical expedient had been met. As a result, we will continue to recognize the revenue associated with our drilling contracts under Topic 606. Therefore, we do not expect any change in our revenue recognition patterns or disclosures as a result of our adoption of Topic 842.

With respect to leases whereby we are the lessee, we elected several practical expedients afforded under Topic 842. We elected the package of practical expedients permitted under the transition guidance of Topic 842, including the hindsight practical expedient which permits entities to use hindsight in determining the lease term and assessing impairment. We also elected the practical expedient to not separate lease components from non-lease components for all asset classes, with the exception of office space. Furthermore, we also elected the practical expedient that permits entities not to apply the recognition requirements for leases with a term of 12 months or less. Upon adoption of Update 2016-02 on January 1, 2019, we recognized lease liabilities and right-of-use assets of $64.6 million and $53.7 million, respectively. See "Note 14 - Leases" for additional information.

Derivatives and Hedging - In August 2017, the Financial Accounting Standards Board (the "FASB") issued ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities ("Update 2017-12"), which makes more hedging strategies eligible for hedge accounting, amends presentation and disclosure requirements and changes how companies assess effectiveness, including the elimination of separate measurement and recognition of ineffectiveness on designated hedging instruments. This update is effective for annual and interim periods beginning after December 15, 2018, with early adoption permitted. We adopted Update 2017-12 effective January 1, 2019. As a result, beginning on the effective date, we no longer separately measure and recognize ineffectiveness on our designated cash flow hedges. Update 2017-02 requires a modified retrospective adoption approach whereby amounts previously recorded to earnings for hedge ineffectiveness on hedging relationships that existed as of the adoption date are recorded as a cumulative effect adjustment to opening retained earnings. As of our adoption date, we had no amounts previously recorded for ineffectiveness for hedging relationships that existed as of our adoption date and therefore no cumulative effect adjustment to retained earnings was recorded.


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Accounting pronouncements to be adopted

Income Taxes - In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes ("Update 2019-12"), which removes certain exceptions for investments, intraperiod allocations and interim tax calculations and adds guidance to reduce complexity in accounting for income taxes. We will be required to adopt the amended guidance in annual and interim periods beginning after December 15, 2020, with early adoption permitted. The various amendments in Update 2019-12 are applied on a retrospective basis, modified retrospective basis and prospective basis, depending on the amendment. We are in the process of evaluating the impact this amendment will have on our consolidated financial statements.

Defined Benefit Plans - In August 2018, the FASB issued ASU 2018-14, Compensation – Retirement Benefits – Defined Benefit Plans – General (Subtopic 715-20): Disclosure Framework – Changes to the Disclosure Requirements for Defined Benefit Plans ("Update 2018-14"), which modifies the disclosure requirements for employers that sponsor defined benefit pension or other post-retirement plans. We will be required to adopt the amended guidance in annual and interim reports beginning January 1, 2021, with early adoption permitted. Adoption is required to be applied on a retrospective basis to all periods presented. We will adopt the new standard effective January 1, 2021 and do not expect the adoption of Update 2018-14 to have a material impact on our consolidated financial statements.

Credit Losses - In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments ("Update 2016-13"), which requires companies to measure credit losses of financial instruments, including customer accounts receivable, utilizing a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. Subsequent to the issuance of Update 2016-13, the FASB issued several additional Accounting Standard Updates to clarify implementation guidance, provide narrow-scope improvements and provide additional disclosure guidance. Update 2016-13 is effective for fiscal years beginning after December 15, 2019, with early adoption permitted. We will adopt the new standard effective January 1, 2020 and do not expect the adoption of Update 2016-13 to have a material impact on our consolidated financial statements.

With the exception of the updated standards discussed above, there have been no accounting pronouncements issued and not yet effective that have significance, or potential significance, to our consolidated financial statements.
    
2.  REVENUE FROM CONTRACTS WITH CUSTOMERS
 
Our drilling contracts with customers provide a drilling rig and drilling services on a day rate contract basis. Under day rate contracts, we provide an integrated service that includes the provision of a drilling rig and rig crews for which we receive a daily rate that may vary between the full rate and zero rate throughout the duration of the contractual term, depending on the operations of the rig.

We also may receive lump-sum fees or similar compensation for the mobilization, demobilization and capital upgrades of our rigs. 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.

Our integrated drilling service provided under each drilling contract is a single performance obligation satisfied over time and comprised of a series of distinct time increments, or service periods. Total revenue is determined for each individual drilling contract by estimating both fixed and variable consideration expected to be earned over the contract term. Fixed consideration generally relates to activities such as mobilization, demobilization and capital upgrades of our rigs that are not distinct performance obligations within the context of our contracts and is recognized on a straight-line basis over the contract term. Variable consideration generally relates to distinct service periods during the contract term and is recognized in the period when the services are performed.

The amount estimated for variable consideration is only recognized as revenue to the extent that it is probable that a significant reversal will not occur during the contract term. We have applied the optional exemption afforded in Update 2014-09, Revenue from Contracts with Customers (Topic 606), and have not disclosed the variable

104



consideration related to our estimated future day rate revenues. The remaining duration of our drilling contracts based on those in place as of December 31, 2019 was between approximately one month and four years.

Day Rate Drilling Revenue

Our drilling contracts provide for payment on a day rate basis and include a rate schedule with higher rates for periods when the drilling unit is operating and lower rates or zero rates for periods when drilling operations are interrupted or restricted. The day rate invoiced to the customer is determined based on the varying rates applicable to specific activities performed on an hourly basis or other time increment basis. Day rate consideration is allocated to the distinct hourly or other time increment to which it relates within the contract term and is generally recognized consistent with the contractual rate invoiced for the services provided during the respective period. Invoices are typically issued to our customers on a monthly basis and payment terms on customer invoices typically range from 30 to 45 days.

Certain of our contracts contain performance incentives whereby we may earn a bonus based on pre-established performance criteria. Such incentives are generally based on our performance over individual monthly time periods or individual wells. Consideration related to performance bonus is generally recognized in the specific time period to which the performance criteria was attributed.

We may receive termination fees if certain drilling contracts are terminated by the customer prior to the end of the contractual term. Such compensation is recognized as revenue when our performance obligation is satisfied, the termination fee can be reasonably measured and collection is probable.
 
Mobilization / Demobilization Revenue

In connection with certain contracts, we receive lump-sum fees or similar compensation for the mobilization of equipment and personnel prior to the commencement of drilling services or the demobilization of equipment and personnel upon contract completion. Fees received for the mobilization or demobilization of equipment and personnel are included in operating revenues. The costs incurred in connection with the mobilization and demobilization of equipment and personnel are included in contract drilling expense.

Mobilization fees received prior to commencement of drilling operations are recorded as a contract liability and amortized on a straight-line basis over the contract term. Demobilization fees expected to be received upon contract completion are estimated at contract inception and recognized on a straight-line basis over the contract term. In some cases, demobilization fees may be contingent upon the occurrence or non-occurrence of a future event. In such cases, this may result in cumulative-effect adjustments to demobilization revenues upon changes in our estimates of future events during the contract term.
 
Capital Upgrade / Contract Preparation Revenue

In connection with certain contracts, we receive lump-sum fees or similar compensation for requested capital upgrades to our drilling rigs or for other contract preparation work. Fees received for requested capital upgrades and other contract preparation work are recorded as a contract liability and amortized on a straight-line basis over the contract term to operating revenues. Costs incurred for capital upgrades are capitalized and depreciated over the useful life of the asset.

Contract Assets and Liabilities

Contract assets represent amounts recognized as revenue but for which the right to invoice the customer is dependent upon our future performance. Once the previously recognized revenue is invoiced, the corresponding contract asset, or a portion thereof, is transferred to accounts receivable. Contract liabilities generally represent fees received for mobilization or capital upgrades.
    

105



Contract assets and liabilities are presented net on our consolidated balance sheet on a contract-by-contract basis. Current contract assets and liabilities are included in other current assets and accrued liabilities and other, respectively, and noncurrent contract assets and liabilities are included in other assets and other liabilities, respectively, on our consolidated balance sheets.

The following table summarizes our contract assets and contract liabilities (in millions):
 
December 31, 2019
 
December 31, 2018
Current contract assets
$
3.5

 
$
4.0

Current contract liabilities (deferred revenue)
$
30.0

 
$
56.9

Noncurrent contract liabilities (deferred revenue)
$
9.7

 
$
20.5

    
Changes in contract assets and liabilities during the period are as follows (in millions):
 
Contract Assets
 
Contract Liabilities
Balance as of January 1, 2019
$
4.0

 
$
77.4

Contract assets and liabilities acquired in the Rowan Transaction
8.4

 
5.3

Revenue recognized in advance of right to bill customer
1.3

 

Increase due to cash received

 
42.9

Decrease due to amortization of deferred revenue that was included in the beginning contract liability balance

 
(56.3
)
Decrease due to amortization of deferred revenue that was added during the period

 
(29.6
)
Decrease due to transfer to receivables during the period
(10.2
)
 

Balance as of December 31, 2019
$
3.5

 
$
39.7



Deferred Contract Costs

Costs incurred for upfront rig mobilizations and certain contract preparations are attributable to our future performance obligation under each respective drilling contract. Such costs are deferred and amortized on a straight-line basis over the contract term. Demobilization costs are recognized as incurred upon contract completion. Costs associated with the mobilization of equipment and personnel to more promising market areas without contracts are expensed as incurred. Deferred contract costs were included in other current assets and other assets on our consolidated balance sheets and totaled $19.7 million and $23.5 million as of December 31, 2019 and 2018, respectively. Amortization of such costs totaled $42.1 million, $34.0 million and $28.1 million for the years ended December 31, 2019, 2018 and 2017, respectively.

Deferred Certification Costs

We must obtain certifications from various regulatory bodies in order to operate our drilling rigs and must maintain such certifications through periodic inspections and surveys. The costs incurred in connection with maintaining such certifications, including inspections, tests, surveys and drydock, as well as remedial structural work and other compliance costs, are deferred and amortized on a straight-line basis over the corresponding certification periods. Deferred regulatory certification and compliance costs were included in other current assets and other assets on our consolidated balance sheets and totaled $10.8 million and $13.6 million as of December 31, 2019 and 2018, respectively. Amortization of such costs totaled $10.3 million, $12.4 million and $12.1 million for the years ended December 31, 2019, 2018 and 2017, respectively.


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Future Amortization of Contract Liabilities and Deferred Costs

Our contract liabilities and deferred costs are amortized on a straight-line basis over the contract term or corresponding certification period to operating revenues and contract drilling expense, respectively. Expected future amortization of our contract liabilities and deferred costs recorded as of December 31, 2019 is set forth in the table below (in millions):

 
2020
 
2021
 
2022
 
2023 & Thereafter
 
 Total
Amortization of contract liabilities
$
30.0

 
$
7.8

 
$
1.9

 
$

 
$
39.7

Amortization of deferred costs
$
23.2

 
$
5.7

 
$
1.2

 
$
0.4

 
$
30.5


3. ROWAN TRANSACTION

On October 7, 2018, we entered into a transaction agreement (the "Transaction Agreement") with Rowan. On April 11, 2019 (the "Transaction Date"), we completed our combination with Rowan pursuant to the Transaction Agreement (the "Rowan Transaction"). Rowan's financial results are included in our consolidating results beginning on the Transaction Date. The Rowan Transaction enhanced the market leadership of the combined company with a fleet of high-specification floaters and jackups and positions us well to meet increasing and evolving customer demand. The increased scale, diversification and financial strength of the combined company provides us advantages to better serve our customers.

Consideration

As a result of the Rowan Transaction, Rowan shareholders received 2.75 Valaris Class A Ordinary shares for each share of Rowan Class A ordinary share, representing a value of $43.67 per Rowan share based on a closing price of $15.88 per Valaris share on April 10, 2019, the last trading day before the Transaction Date. Total consideration delivered in the Rowan Transaction consisted of 88.3 million Valaris shares with an aggregate value of $1.4 billion, inclusive of $2.6 million for the estimated fair value of replacement employee equity awards. Upon closing of the Rowan Transaction, we effected a consolidation (being a reverse stock split under English law) where every four existing Class A ordinary shares, each with a nominal value of $0.10, were consolidated into one Class A ordinary share, each with a nominal value of $0.40 (the "Reverse Stock Split"). All share and per share data included in this report have been retroactively adjusted to reflect the Reverse Stock Split.

Assets and Liabilities Acquired
    
Valaris is considered to be the acquirer for accounting purposes. As a result, Rowan's assets and liabilities acquired in the Rowan Transaction were recorded at their estimated fair values as of the Transaction Date under the acquisition method of accounting. When the fair value of the net assets acquired exceeds the consideration transferred in an acquisition, the difference is recorded as a bargain purchase gain in the period in which the transaction occurs. With the exception of certain legal and tax exposures as well as the fair value of materials and supplies, we have substantially completed our fair value assessments of assets acquired and liabilities assumed. While certain adjustments may be recorded during the remainder of the measurement period, we do not expect them to be material.


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The provisional amounts recorded for assets and liabilities acquired are based on preliminary estimates of their fair values as of the Transaction Date and are as follows (in millions):
 
Amounts Recognized as of Transaction Date
 
Measurement Period Adjustments (1)
 
Estimated Fair Value
Assets:
 
 
 
 
 
Cash and cash equivalents
$
931.9

 
$

 
$
931.9

Accounts receivable(2)
207.1

 
(3.6
)
 
203.5

Other current assets
101.6

 
(2.4
)
 
99.2

Long-term notes receivable from ARO
454.5

 

 
454.5

Investment in ARO
138.8

 
2.5

 
141.3

Property and equipment
2,989.8

 
(25.8
)
 
2,964.0

Other assets
41.7

 
1.3

 
43.0

Liabilities:
 
 
 
 
 
Accounts payable and accrued liabilities
259.4

 
13.7

 
273.1

Current portion of long-term debt
203.2

 

 
203.2

Long-term debt
1,910.9

 

 
1,910.9

Other liabilities
376.3

 
34.1

 
410.4

Net assets acquired
2,115.6

 
(75.8
)
 
2,039.8

Less: Merger consideration
(1,402.8
)
 

 
(1,402.8
)
Bargain purchase gain
$
712.8

 
$
(75.8
)
 
$
637.0


(1) The measurement period adjustments reflect changes in the estimated fair values of certain assets and liabilities, primarily related to long-lived assets, deferred income taxes and uncertain tax positions. The measurement period adjustments were recorded to reflect new information obtained about facts and circumstances existing as of the Transaction Date and did not result from subsequent intervening events.
(2) Gross contractual amounts receivable totaled $208.3 million as of the Transaction Date.

Bargain Purchase Gain

The estimated fair values assigned to assets acquired net of liabilities assumed exceeded the consideration transferred, resulting in a bargain purchase gain primarily driven by the decline in our share price from $33.92 to $15.88 between the last trading day prior to the announcement of the Rowan Transaction and the Transaction Date.

Transaction-Related Costs

Merger-related costs were expensed as incurred and consisted of various advisory, legal, accounting, valuation and other professional or consulting fees totaling $18.0 million for the year ended December 31, 2019. These costs are included in general and administrative expense in our consolidated statements of operations.

Materials and Supplies

We recorded materials and supplies at an estimated fair value of $83.0 million. Materials and supplies consist of consumable parts and supplies maintained on drilling rigs and in shore-based warehouse locations for use in operations and are generally comprised of items of low per unit cost and high reorder frequency. We estimated the fair value of Rowan's materials and supplies primarily using a market approach.


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Equity Method Investment in ARO

The equity method investment in ARO was recorded at its estimated fair value as of the Transaction Date. See Note 4 for additional information on ARO. We estimated the fair value of the equity investment primarily by applying an income approach, using projected discounted cash flows of the underlying assets, a risk-adjusted discount rate and an estimated effective income tax rate.

Property and Equipment

Property and equipment acquired in connection with the Rowan Transaction consisted primarily of drilling rigs and related equipment, including four drillships and 19 jackup rigs (exclusive of two jackups marked for retirement).  We recorded property and equipment acquired at its estimated fair value of $3.0 billion. We estimated the fair value of the rigs and equipment by applying an income approach, using projected discounted cash flows, a risk-adjusted discount rate and an estimated effective income tax rate. The estimated remaining useful lives for Rowan's drilling rigs, which ranged from 16 to 35 years based on original estimated useful lives of 30 to 35 years.

Intangible Assets and Liabilities

We recorded intangible assets and liabilities of $16.2 million and $2.1 million, respectively, representing the estimated fair value of Rowan's firm contracts in place at the Transaction Date with favorable or unfavorable contract terms compared to then-market day rates for comparable drilling rigs. The various factors considered in the determination of these fair values were (1) the contracted day rate for each contract, (2) the remaining term of each contract, (3) the rig class and (4) the market conditions for each respective rig class at the Transaction Date. The intangible assets and liabilities were calculated based on the present value of the difference in cash flows over the remaining contract term as compared to a hypothetical contract with the same remaining term at an estimated then-current market day rate using a risk-adjusted discount rate and an estimated effective income tax rate.

Amortization of the intangible assets and liabilities resulted in a net reduction in operating revenues of $3.6 million for the year ended December 31, 2019. The remaining balance of intangible assets and liabilities of $11.9 million and $1.4 million, respectively, was included in other assets and other liabilities, respectively, on our consolidated balance sheet of December 31, 2019. These balances will be amortized to operating revenues over the respective remaining contract terms on a straight-line basis. As of December 31, 2019, the remaining terms of the underlying contracts is approximately 2 years. Amortization of these intangibles is expected to result in a reduction to revenue of $5.1 million and $5.4 million in 2020 and 2021, respectively.

Pension and Other Post-retirement benefit plans

We remeasured the fair value of plan assets and benefit obligations for the pension and other-post retirement benefit plans assumed as of April 11, 2019. We used a measurement date of April 11, 2019 for determining net periodic benefit costs.

Long-term Debt

We recorded Rowan's long-term debt at its estimated fair value as of the Transaction Date, which was based on quoted market prices as of April 10, 2019.


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Deferred Taxes

The Rowan Transaction was executed through the acquisition of Rowan's outstanding ordinary shares and, therefore, the historical tax bases of the acquired assets and liabilities, net operating losses and other tax attributes of Rowan, were acquired as of the Transaction Date.  However, adjustments were recorded to recognize deferred tax assets and liabilities for the tax effects of differences between acquisition date fair values and tax bases of assets acquired and liabilities assumed. Additionally, the interaction of our and Rowan's tax attributes that impacted the deferred taxes of the combined entity were also recognized as part of acquisition accounting. As of the Transaction Date, a decrease of $99.0 million to Rowan's historical net deferred tax assets was recognized.

Deferred tax assets and liabilities recognized in connection with the Rowan Transaction were measured at rates enacted as of the Transaction Date.  Tax rate changes, or any deferred tax adjustments for new tax legislation, following the Transaction Date will be reflected in our operating results in the period in which the change in tax laws or rate is enacted.

Uncertain Tax Positions

Uncertain tax positions assumed in a business combination are measured at the largest amount of the tax benefit that is greater than 50% likely of being realized upon effective settlement with a taxing authority that has full knowledge of all relevant information. As of the Transaction Date, Rowan had previously recognized net liabilities for uncertain tax positions totaling $50.4 million.

During 2019, we received income tax assessments from Luxembourg tax authorities related to certain filing positions taken by Rowan in prior years for several of Rowan’s Luxembourg subsidiaries totaling approximately €142.0 million (approximately $159.0 million converted using the current period-end exchange rate). We are contesting these assessments and have filed applications for appeal. As of the Transaction Date, we recognized liabilities under acquisition accounting of €47.0 million (approximately $52.0 million converted using the current period-end exchange rate) in connection with the Luxembourg assessments, which reflected the amount of the Rowan filing positions that we concluded, on a preliminary basis, we would not more-likely-than-not sustain. As a result of our continued review and analysis of facts and circumstances that existed at the Transaction Date, we recognized additional liabilities of €46.0 million (approximately $52.6 million converted using the current period-end exchange rate) as measurement period adjustments.

As a result, the amount recognized on our consolidated balance sheet related to the Luxembourg income tax assessments totaled €93.0 million (approximately $104.6 million converted using the current period-end exchange rates) as of December 31, 2019. Our ongoing evaluation of the relevant facts and circumstances surrounding these positions may result in further revisions to this estimate, which could be material. We cannot predict or provide assurance as to the ultimate outcome of the Luxembourg tax assessments.

Revenues and Earnings of Rowan
 
Our consolidated statement of operations for the year ending December 31, 2019 included revenues of $448.0 million and net losses of $122.7 million.



110



Unaudited Pro Forma Impact of the Rowan Transaction

The following unaudited supplemental pro forma results present consolidated information as if the Rowan Transaction was completed on January 1, 2018. The pro forma results include, among others, (1) the amortization associated with acquired intangible assets and liabilities, (2) a reduction in depreciation expense for adjustments to property and equipment, (3) the amortization of premiums and discounts recorded on Rowan's debt, (4) removal of the historical amortization of unrealized gains and losses related to Rowan's pension plans and (5) the amortization of basis differences in assets and liabilities of ARO. The pro forma results do not include any potential synergies or non-recurring charges that may result directly from the Rowan Transaction.

(unaudited)
(in millions, except per share amounts)
Year Ended
 
2019(1)
 
2018(2)
Revenues
$
2,240.5

 
$
2,530.4

Net loss
$
(994.3
)
 
$
(796.5
)
Earnings per share - basic and diluted
$
(3.80
)
 
$
(4.05
)
(1) Pro forma net loss per share was adjusted to exclude an aggregate $108.1 million of transaction-related and integration costs incurred by Ensco and Rowan during 2019 and the $637.0 million bargain purchase gain.

(2) Pro forma net loss per share was adjusted to exclude an aggregate $13.8 million of transaction-related and integration costs incurred by Ensco and Rowan during 2018.


Note 4 -     Equity Method Investment in ARO

Background

During 2016, Rowan and Saudi Aramco entered into an agreement to create a 50/50 joint venture (the "Shareholders' Agreement") to own, manage and operate offshore drilling rigs in Saudi Arabia. The new entity, ARO, was formed in May 2017 with each of Rowan and Saudi Aramco contributing $25 million to be used for working capital needs.

In October 2017, Rowan sold rigs Bob Keller, J.P. Bussell and Gilbert Rowe to ARO and Saudi Aramco sold SAR 201 and related assets to ARO in each case for cash. Upon completion of the rig sales, ARO was deemed to have commenced operations. Saudi Aramco subsequently sold another rig, SAR 202, to ARO in December 2017 for cash and in October 2018, Rowan sold two additional jackup rigs, the Scooter Yeargain and the Hank Boswell, to ARO for cash. As a result of these rig sales, ARO owned seven jackup rigs as of the Transaction Date.

During 2017 and 2018, Rowan contributed cash to ARO in exchange for 10-year shareholder notes receivable at a stated interest rate of LIBOR plus two percent. As of December 31, 2019, the carrying amount of the long-term notes receivable from ARO was $452.9 million. The Shareholders’ Agreement prohibits the sale or transfer of the shareholder note to a third party, except in certain limited circumstances.

Rigs purchased by ARO will receive contracts from Saudi Aramco for an aggregate 15 years, renewed and re-priced every three years, provided that the rigs meet the technical and operational requirements of Saudi Aramco. Each of the seven rigs owned by ARO is currently operating under its initial three-year contract.

    Additionally, prior to the Rowan Transaction, Rowan entered into agreements with ARO to lease nine rigs to ARO (the "Lease Agreements"). The rigs are leased to ARO through bareboat charter arrangements whereby substantially all operating costs are incurred by ARO. As of December 31, 2019, all nine of the rigs were operating under three-year drilling contracts with Saudi Aramco.

111




Valaris and Saudi Aramco have agreed to take all steps necessary to ensure that ARO purchases 20 newbuild jackup rigs ratably over an approximate 10 -year period. In January 2020, ARO ordered the first two newbuild jackups, each with a price of $176 million, for delivery scheduled in 2022. The partners intend for the newbuild jackup rigs to be financed out of available cash from ARO's operations and/or funds available from third-party debt financing. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. The partners agreed that Saudi Aramco, as a customer, will provide drilling contracts to ARO in connection with the acquisition of the newbuild rigs. The initial contracts provided by Saudi Aramco for each of the newbuild rigs will be for an eight-year term. The day rate for the initial contracts for each newbuild rig will be determined using a pricing mechanism that targets a six-year payback period for construction costs on an EBITDA basis. The initial eight-year contracts will be followed by a minimum of another eight years of term, re-priced in three-year intervals based on a market pricing mechanism.

Upon establishment of ARO, Rowan also entered into (1) an agreement to provide certain back-office services for a period of time until ARO develops its own infrastructure (the "Transition Services Agreement"), and (2) an agreement to provide certain Rowan employees through secondment arrangements to assist with various onshore and offshore services for the benefit of ARO (the "Secondment Agreement"). These agreements remain in place subsequent to the Rowan Transaction. Pursuant to these agreements, we or our seconded employees provide various services to ARO, and in return, ARO provides remuneration for those services. From time to time, we may also sell equipment or supplies to ARO.

Summarized Financial Information

The operating revenues of ARO presented below reflect revenues earned under drilling contracts with Saudi Aramco for the seven ARO-owned jackup rigs and the rigs leased from us that operated from the Transaction Date through December 31, 2019.

The contract drilling expenses, depreciation and general and administrative expenses presented below are also for the period from the Transaction Date through December 31, 2019. Contract drilling expense is inclusive of the bareboat charter fees for the rigs leased from us. Cost incurred under the Secondment Agreement are included in contract drilling expense and general and administrative, depending on the function to which the seconded employee's service relates. Substantially all costs incurred under the Transition Services Agreement are included in general and administrative. See additional discussion below regarding these related-party transactions.

Summarized financial information for ARO is as follows (in millions):
 
 
April 11, 2019 - December 31, 2019
Revenues
 
$
410.5

Operating expenses
 
 
   Contract drilling (exclusive of depreciation)
 
280.2

   Depreciation
 
40.3

   General and administrative
 
27.1

Operating income
 
62.9

Other expense, net
 
28.6

Provision for income taxes
 
9.7

Net income
 
$
24.6



112



 
 
December 31, 2019
Current assets
 
$
407.2

Non-current assets
 
874.8

Total assets
 
$
1,282.0

 
 
 
Current liabilities
 
$
183.2

Non-current liabilities
 
1,015.5

Total liabilities
 
$
1,198.7



Equity in Earnings of ARO

We account for our interest in ARO using the equity method of accounting and only recognize our portion of ARO's net income, adjusted for basis differences as discussed below, which is included in equity in earnings of ARO in our consolidated statements of operations. ARO is a variable interest entity; however, we are not the primary beneficiary and therefore do not consolidate ARO. Judgments regarding our level of influence over ARO included considering key factors such as: each partner's ownership interest, representation on the board of managers of ARO and ability to direct activities that most significantly impact ARO's economic performance, including the ability to influence policy-making decisions.

As a result of the Rowan Transaction, we recorded our equity method investment in ARO at its estimated fair value on the Transaction Date. Additionally, we computed the difference between the fair value of ARO's net assets and the carrying value of those net assets in ARO's US GAAP financial statements ("basis differences"). The basis differences primarily relate to ARO's long-lived assets and the recognition of intangible assets associated with certain of ARO's drilling contracts that were determined to have favorable terms as of the Transaction Date. The basis differences are amortized over the remaining life of the assets or liabilities to which they relate and are recognized as an adjustment to the equity in earnings of ARO in our consolidated statements of operations. The amortization of those basis differences are combined with our 50% interest in ARO's net income. A reconciliation of those components is presented below (in millions):
 
 
April 11, 2019 - December 31, 2019
50% interest in ARO net income
 
$
12.3

Amortization of basis differences
 
(24.9
)
Equity in earnings of ARO
 
$
(12.6
)


Related-Party Transactions

Revenues recognized by us related to the Lease Agreements, Transition Services Agreement and Secondment Agreement are as follows (in millions):
 
 
Year Ended December 31, 2019
Lease revenue
 
$
58.2

Secondment revenue
 
49.9

Transition Services revenue
 
17.3

Total revenue from ARO (1)
 
$
125.4


(1) 
All of the revenues presented above are included in our Other segment in our segment disclosures. See Note 15 for additional information.


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Amounts receivable from ARO related to the above items totaled $21.8 million as of December 31, 2019 and are included in accounts receivable, net, on our consolidated balance sheet. Accounts payable to ARO totaled $0.7 million as of December 31, 2019.

We also have an agreement between us and ARO, pursuant to which ARO will reimburse us for certain capital expenditures related to the shipyard upgrade projects for VALARIS JU-147 and VALARIS JU-148. As of December 31, 2019, $14.2 million related to reimbursement of these expenditures was included in accounts receivable, net, on our consolidated balance sheet.

During 2017 and 2018, Rowan contributed cash to ARO in exchange for 10-year shareholder notes receivable at a stated interest rate of LIBOR plus two percent. Interest is recognized as interest income in our consolidated statement of operations and totaled $16.8 million for the period from the Transaction Date through December 31, 2019, respectively. As of December 31, 2019, we had no interest receivable from ARO.

The following table summarizes the maturity schedule of our notes receivable from ARO as of December 31, 2019 (in millions):

Maturity Date
Principal Amount
October 2027
$
275.2

October 2028
177.7

Total
$
452.9



Maximum Exposure to Loss

The following summarizes the total assets and liabilities as reflected in our consolidated balance sheet as well as our maximum exposure to loss related to ARO (in millions). Our maximum exposure to loss is limited to (1) our equity investment in ARO; (2) the outstanding balance on our shareholder notes receivable; and (3) other receivables for services provided to ARO, partially offset by payables for services received.
 
December 31, 2019
Total assets
$
623.5

Less: total liabilities
.7

Maximum exposure to loss
$
622.8




5.  FAIR VALUE MEASUREMENTS

The following fair value hierarchy table categorizes information regarding our financial assets and liabilities measured at fair value on a recurring basis as of December 31, 2019 and 2018 (in millions):
 
Quoted Prices in
Active Markets
for
Identical Assets
(Level 1)
 
Significant
Other
Observable
Inputs
  (Level 2)
 
Significant
Unobservable
Inputs
(Level 3)
 
Total
As of December 31, 2019
 

 
 

 
 

 
 

Supplemental executive retirement plan assets
$
26.0

 
$

 
$

 
$
26.0

Derivatives, net

 
5.4

 

 
5.4

Total financial assets
$
26.0

 
$
5.4

 
$

 
$
31.4

As of December 31, 2018
 

 
 

 
 

 
 

Supplemental executive retirement plan assets
$
27.2

 
$

 
$

 
$
27.2

Total financial assets
27.2

 

 

 
27.2

Derivatives, net

 
(10.7
)
 

 
(10.7
)
Total financial liabilities
$

 
$
(10.7
)
 
$

 
$
(10.7
)



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Supplemental Executive Retirement Plans

Our Valaris supplemental executive retirement plans (the "SERPs") are non-qualified plans that provide eligible employees an opportunity to defer a portion of their compensation for use after retirement. The SERPs were frozen to the entry of new participants in November 2019 and to future compensation deferrals as of January 1, 2020. Assets held in the SERP were marketable securities measured at fair value on a recurring basis using Level 1 inputs and were included in other assets, net, on our consolidated balance sheets as of December 31, 2019 and 2018.  The fair value measurements of assets held in the SERP were based on quoted market prices. Net unrealized gains of $5.0 million, losses of $700,000 and gains of $4.5 million from marketable securities held in our SERP were included in other, net, in our consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017, respectively.
 
Derivatives

Our derivatives were measured at fair value on a recurring basis using Level 2 inputs as of December 31, 2019 and 2018.  See "Note 8 - Derivative Instruments" for additional information on our derivatives, including a description of our foreign currency hedging activities and related methodologies used to manage foreign currency exchange rate risk. The fair value measurements of our derivatives were based on market prices that are generally observable for similar assets or liabilities at commonly quoted intervals.

Other Financial Instruments

The carrying values and estimated fair values of our debt instruments as of December 31, 2019 and 2018 were as follows (in millions):
 
 
December 31, 2019
 
December 31, 2018
 
 
Carrying
Value
 
Estimated
  Fair
Value
 
Carrying
Value
 
Estimated
  Fair
Value
6.875% Senior notes due 2020
 
$
124.8

 
$
117.3

 
$
127.5

 
$
121.6

4.70% Senior notes due 2021
 
113.2

 
95.5

 
112.7

 
101.8

4.875% Senior notes due 2022 (2)
 
599.2

 
460.5

 

 

3.00% Exchangeable senior notes due 2024 (1)
 
699.0

 
607.4

 
666.8

 
575.5

4.50% Senior notes due 2024
 
302.0

 
167.2

 
619.8

 
405.2

4.75% Senior notes due 2024 (2)
 
276.5

 
201.4

 

 

8.00% Senior notes due 2024
 
295.7

 
181.7

 
337.0

 
273.7

5.20% Senior notes due 2025
 
331.7

 
186.7

 
664.4

 
443.9

7.375% Senior notes due 2025 (2)
 
329.2

 
218.6

 

 

7.75% Senior notes due 2026
 
987.1

 
575.1

 
985.0

 
725.5

7.20% Debentures due 2027
 
111.7

 
70.0

 
149.3

 
109.1

7.875% Senior notes due 2040
 
373.3

 
153.5

 
375.0

 
223.2

5.40% Senior notes due 2042 (2)
 
262.8

 
194.4

 

 

5.75% Senior notes due 2044
 
973.3

 
450.0

 
972.9

 
566.3

5.85% Senior notes due 2044 (2)
 
268.8

 
194.8

 

 

Total debt
 
$
6,048.3

 
$
3,874.1

 
$
5,010.4

 
$
3,545.8

     Less: current maturities
 
124.8

 

 

 

Total long-term debt
 
$
5,923.5

 
$
3,874.1

 
$
5,010.4

 
$
3,545.8



(1) 
Our 2024 Convertible Notes were issued with a conversion feature. The 2024 Convertible Notes were separated into their liability and equity components on our consolidated balance sheet. The equity component was initially recorded to additional paid-in capital and as a debt discount that will be amortized to interest expense over

115



the life of the instrument. Excluding the unamortized discount, the carrying value of the 2024 Convertible Notes was $838.3 million and $836.3 million as of December 31, 2019 and 2018, respectively. See "Note 7 - Debt" for additional information on this issuance.

(2) 
These senior notes were assumed by Valaris as a result of the Rowan Transaction.

The estimated fair values of our senior notes and debentures were determined using quoted market prices, which are level 1 inputs. The estimated fair values of our cash and cash equivalents, short-term investments, accounts receivable, notes receivable, trade payables and other liabilities approximated their carrying values as of December 31, 2019 and 2018. Our short-term investments consisted of time deposits with initial maturities in excess of three months but less than one year as of December 31, 2018.

6.  PROPERTY AND EQUIPMENT

Property and equipment as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Drilling rigs and equipment
 
$
17,714.0

 
$
14,542.5

Work-in-progress
 
473.6

 
779.2

Other
 
206.2

 
195.3

 
 
$
18,393.8

 
$
15,517.0


 
Drilling rigs and equipment as of December 31, 2019 increased by $3.2 billion, or 22%, as compared to prior period, primarily due to $3.0 billion of assets acquired from the Rowan Transaction, and $385.0 million due to VALARIS JU-123 which was placed into service in the current period.

Work-in-progress as of December 31, 2019 primarily consisted of $417.4 million related to the construction of ultra-deepwater drillships VALARIS DS-13 and VALARIS DS-14.

Work-in-progress as of December 31, 2018 primarily consisted of $416.8 million related to the construction of ultra-deepwater drillships VALARIS DS-13 and VALARIS DS-14 and $352.4 million related to the construction of VALARIS JU-123, an ultra-premium harsh environment jackup rig.

VALARIS JU-123 was placed into service and reclassified from work-in-progress to drilling rigs and equipment during the year ended December 31, 2019.

Impairment of Long-Lived Assets

On a quarterly basis, we evaluate the carrying value of our property and equipment to identify events or changes in circumstances ("triggering events") that indicate the carrying value may not be recoverable. Together with the Rowan Transaction, and as a result of the evaluation of the strategy of the combined fleet, we determined that a triggering event occurred resulting in the performance of a fleet-wide recoverability test. We determined that estimated undiscounted cash flows were sufficient to cover the rigs carrying values and concluded that no impairments were necessary.

During 2019, we recorded a pre-tax, non-cash loss on impairment of $98.4 million on two older, non-core assets in our fleet upon classification as held-for-sale. We determined that the fair value less cost to sell was lower than each rig's carrying value and concluded that the rigs were impaired.

During 2018, we recorded a pre-tax, non-cash loss on impairment of $40.3 million related to one older non-core jackup rig. We concluded that a triggering event occurred due to the expiration of a legacy higher day rate contract resulting in the performance of a recoverability test. We determined that the estimated undiscounted cash flows over

116



the remaining useful life of the rig were not sufficient to recover the rig’s carrying value and concluded the rig was impaired as of December 31, 2018.

During 2017, we recognized a pre-tax, non-cash loss on impairment of $182.9 million related to older, less capable, non-core assets in our fleet. We determined that the remaining useful life of certain non-core rigs would not extend substantially beyond their current contracts, resulting in triggering events and the performance of recoverability tests. Our estimates of undiscounted cash flows over the revised estimated remaining useful lives were not sufficient to recover each asset’s carrying value. Accordingly, we concluded that two semisubmersibles and one jackup were impaired as of December 31, 2017.

For rigs classified as held-for-sale, we recorded an impairment for the difference between their carrying value and the fair value less costs to sell. We estimated fair value using significant other observable inputs including indicative scrap values based on historical sale prices.
    
For rigs whose carrying values were determined not to be recoverable, we recorded an impairment for the difference between their fair values and carrying values. We estimated the fair values of these rigs by applying an income approach, using projected discounted cash flows. These valuations were based on unobservable inputs that require significant judgments for which there is limited information, including assumptions regarding future day rates, utilization, operating costs and capital requirements. Forecasted day rates and utilization took into account market conditions and our anticipated business outlook.

If the global economy, our overall business outlook and/or our expectations regarding the marketability of one or more of our drilling rigs deteriorate further, we may conclude that a triggering event has occurred and perform a recoverability test that could lead to a material impairment charge in future periods.

7.  DEBT

The carrying value of our long-term debt as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
6.875% Senior notes due 2020
 
$
124.8

 
$
127.5

4.70% Senior notes due 2021
 
113.2

 
112.7

4.875% Senior notes due 2022(3)
 
599.2

 

3.00% Exchangeable senior notes due 2024(2)
 
699.0

 
666.8

4.50% Senior notes due 2024(1)
 
302.0

 
619.8

4.75% Senior notes due 2024(3)
 
276.5

 

8.00% Senior notes due 2024(1)
 
295.7

 
337.0

5.20% Senior notes due 2025(1)
 
331.7

 
664.4

7.375% Senior notes due 2025(3)
 
329.2

 

7.75% Senior notes due 2026
 
987.1

 
985.0

7.20% Debentures due 2027(1)
 
111.7

 
149.3

7.875% Senior notes due 2040
 
373.3

 
375.0

5.40% Senior notes due 2042(3)
 
262.8

 

5.75% Senior notes due 2044
 
973.3

 
972.9

5.85% Senior notes due 2044(3)
 
268.8

 

Total debt
 
$
6,048.3

 
$
5,010.4

Less: current maturities
 
124.8

 

Total long-term debt
 
$
5,923.5


$
5,010.4




117



(1) 
The decline in the carrying value of our 4.50% and 8.00% senior notes due 2024, 5.20% senior notes due 2025 and 7.20% debentures due 2027 resulted from repurchases made pursuant to the tender offer discussed below.

(2) 
Our 2024 Convertible Notes were issued with a conversion feature. The 2024 Convertible Notes were separated into their liability and equity components on our consolidated balance sheet. The equity component was initially recorded to additional paid-in capital and as a debt discount that will be amortized to interest expense over the life of the instrument. Excluding the unamortized discount, the carrying value of the 2024 Convertible Notes was $838.3 million and $836.3 million as of December 31, 2019 and 2018, respectively.

(3) 
These senior notes were acquired in the Rowan Transaction.

2024 Convertible Notes
 
In December 2016, Ensco Jersey Finance Limited, a wholly-owned subsidiary of Valaris plc, issued $849.5 million aggregate principal amount of unsecured 2024 Convertible Notes in a private offering. The 2024 Convertible Notes are fully and unconditionally guaranteed, on a senior, unsecured basis, by Valaris plc and are exchangeable into cash, our Class A ordinary shares or a combination thereof, at our election. Interest on the 2024 Convertible Notes is payable semiannually on January 31 and July 31 of each year. The 2024 Convertible Notes will mature on January 31, 2024, unless exchanged, redeemed or repurchased in accordance with their terms prior to such date. Holders may exchange their 2024 Convertible Notes at their option any time prior to July 31, 2023 only under certain circumstances set forth in the indenture governing the 2024 Convertible Notes. On or after July 31, 2023, holders may exchange their 2024 Convertible Notes at any time. The exchange rate is 17.8336 shares per $1,000 principal amount of notes, representing an exchange price of $56.08 per share, and is subject to adjustment upon certain events. The 2024 Convertible Notes may not be redeemed by us except in the event of certain tax law changes.

Upon conversion of the 2024 Convertible Notes, holders will receive cash, our Class A ordinary shares or a combination thereof, at our election. Our intent is to settle the principal amount of the 2024 Convertible Notes in cash upon conversion. If the conversion value exceeds the principal amount (i.e., our share price exceeds the exchange price on the date of conversion), we expect to deliver shares equal to our conversion obligation in excess of the principal amount. During each respective reporting period that our average share price exceeds the exchange price, an assumed number of shares required to settle the conversion obligation in excess of the principal amount will be included in the denominator for our computation of diluted EPS using the treasury stock method. See "Note 1 - Description of the Business and Summary of Significant Accounting Policies" for additional information regarding the impact to our EPS.

The 2024 Convertible Notes were separated into their liability and equity components and included in long-term debt and additional paid-in capital on our consolidated balance sheet, respectively. The carrying amount of the liability component was calculated by measuring the estimated fair value of a similar liability that does not include an associated conversion feature. The carrying amount of the equity component representing the conversion feature was determined by deducting the fair value of the liability component from the principal amount of the 2024 Convertible Notes. The difference between the carrying amount of the liability and the principal amount is amortized to interest expense over the term of the 2024 Convertible Notes, together with the coupon interest, resulting in an effective interest rate of approximately 8% per annum. The equity component is not remeasured if we continue to meet certain conditions for equity classification.

The costs related to the issuance of the 2024 Convertible Notes were allocated to the liability and equity components based on their relative fair values. Issuance costs attributable to the liability component are amortized to interest expense over the term of the notes and the issuance costs attributable to the equity component were recorded to additional paid-in capital on our consolidated balance sheet.


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As of December 31, 2019 and 2018, the 2024 Convertible Notes consist of the following (in millions):
Liability component:
 
2019
 
2018
Principal
 
$
849.5

 
$
849.5

Less: Unamortized debt discount and issuance costs
 
(150.5
)
 
(182.7
)
Net carrying amount
 
699.0

 
666.8

Equity component, net
 
$
220.0

 
$
220.0


During the year ended December 31, 2019, 2018 and 2017, we recognized $25.5 million associated with coupon interest. Amortization of debt discount and issuance costs were $32.5 million, $31.0 million and $31.4 million for the years ended December 31, 2019, 2018 and 2017, respectively.

The indenture governing the 2024 Convertible Notes contains customary events of default, including failure to pay principal or interest on such notes when due, among others. The indenture also contains certain restrictions, including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions.

  Senior Notes

As a result of the Rowan Transaction, we acquired the following debt issued by Rowan Companies, Inc. ("RCI") and guaranteed by Rowan: (1) $201.4 million in aggregate principal amount of 7.875% unsecured senior notes, which was repaid at maturity in August 2019, (2) $620.8 million in aggregate principal amount of 4.875% unsecured senior notes due 2022 (the "Rowan 2022 Notes"), (3) $398.1 million in aggregate principal amount of 4.75% unsecured senior notes due 2024 (the "Rowan 2024 Notes"), (4) $500.0 million in aggregate principal amount of 7.375% unsecured senior notes due 2025 (the "Rowan 2025 Notes"), (5) $400.0 million in aggregate principal amount of 5.4% unsecured senior notes due 2042 (the "Rowan 2042 Notes") and (6) $400.0 million in aggregate principal amount of 5.85% unsecured senior notes due 2044 (the "Rowan 2044 Notes" and collectively, the "Rowan Notes"). Upon closing of the Rowan Transaction, we terminated Rowan's outstanding credit facilities. On February 3, 2020, Rowan and RCI transferred substantially all their assets on a consolidated basis to Valaris plc, Valaris plc became the obligor on the notes and Rowan and RCI were relieved of their obligations under the notes and the related indenture.

On January 26, 2018, we issued $1.0 billion aggregate principal amount of unsecured 7.75% senior notes due 2026 (the "2026 Notes") at par, net of $16.5 million of debt issuance costs. Interest on the 2026 Notes is payable semiannually on February 1 and August 1 of each year.

During 2017, we exchanged $332.0 million aggregate principal amount of unsecured 8.00% senior notes due 2024 (the “8 % 2024 Notes”) for certain amounts of our outstanding senior notes due 2019, 2020 and 2021. Interest on the 8% 2024 Notes is payable semiannually on January 31 and July 31 of each year.
 
During 2015, we issued $700.0 million aggregate principal amount of unsecured 5.20% senior notes due 2025 (the “2025 Notes”) at a discount of $2.6 million and $400.0 million aggregate principal amount of unsecured 5.75% senior notes due 2044 (the “New 2044 Notes”) at a discount of $18.7 million in a public offering. Interest on the 2025 Notes is payable semiannually on March 15 and September 15 of each year. Interest on the New 2044 Notes is payable semiannually on April 1 and October 1 of each year.

During 2014, we issued $625.0 million aggregate principal amount of unsecured 4.50% senior notes due 2024 (the "2024 Notes") at a discount of $0.9 million and $625.0 million aggregate principal amount of unsecured 5.75% senior notes due 2044 (the "Existing 2044 Notes" and together with the New 2044 Notes, the "2044 Notes") at a discount of $2.8 million. Interest on the 2024 Notes and the Existing 2044 Notes is payable semiannually on April 1 and October 1 of each year. The Existing 2044 Notes and the New 2044 Notes are treated as a single series of debt securities under the indenture governing the notes.


119



During 2011, we issued $1.5 billion aggregate principal amount of unsecured 4.70% senior notes due 2021 (the “2021 Notes”) at a discount of $29.6 million in a public offering. Interest on the 2021 Notes is payable semiannually on March 15 and September 15 of each year.

Upon consummation of the Pride International LLC ("Pride") acquisition during 2011, we assumed outstanding debt comprised of $900.0 million aggregate principal amount of unsecured 6.875% senior notes due 2020$500.0 million aggregate principal amount of unsecured 8.5% senior notes due 2019 and $300.0 million aggregate principal amount of unsecured 7.875% senior notes due 2040 (collectively, the "Acquired Notes" and together with the Rowan Notes, 2021 Notes, 8% 2024 Notes, 2024 Notes, 2025 Notes, 2026 Notes and 2044 Notes, the "Senior Notes").  Valaris plc has fully and unconditionally guaranteed the performance of all Pride obligations with respect to the Acquired Notes.  See "Note 17 - Guarantee of Registered Securities" for additional information on the guarantee of the Acquired Notes.
   
We may redeem the Senior Notes in whole at any time, or in part from time to time, prior to maturity. If we elect to redeem the Rowan 2022 Notes, Rowan 2024 Notes, 8% 2024 Notes, 2024 Notes, 2025 Notes, Rowan 2025 Notes and 2026 Notes before the date that is three months prior to the maturity date or the Rowan 2042 Notes, Rowan 2044 Notes and 2044 Notes before the date that is six months prior to the maturity date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued and unpaid interest and a "make-whole" premium. If we elect to redeem these notes on or after the aforementioned dates, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued and unpaid interest but we are not required to pay a "make-whole" premium.

We may redeem each series of the 2021 Notes and the Acquired Notes, in whole or in part, at any time at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a "make-whole" premium.

The indentures governing the Senior Notes contain customary events of default, including failure to pay principal or interest on such notes when due, among others. The indentures governing the Senior Notes also contain certain restrictions, including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions.

  Debentures Due 2027

During 1997, Ensco International Incorporated issued $150.0 million of unsecured 7.20% Debentures due 2027 (the "Debentures"). Interest on the Debentures is payable semiannually on May 15 and November 15 of each year. We may redeem the Debentures, in whole or in part, at any time prior to maturity, at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a "make-whole" premium. During 2009, Ensco plc entered into a supplemental indenture to unconditionally guarantee the principal and interest payments on the Debentures. See "Note 17 - Guarantee of Registered Securities" for additional information on the guarantee of the Debentures.

The Debentures and the indenture pursuant to which the Debentures were issued also contain customary events of default, including failure to pay principal or interest on the Debentures when due, among others. The indenture also contains certain restrictions, including, among others, restrictions on our ability and the ability of our subsidiaries to create or incur secured indebtedness, enter into certain sale/leaseback transactions and enter into certain merger or consolidation transactions.


120



  Tender Offers and Open Market Repurchases

On June 25, 2019, we commenced cash tender offers for certain series of senior notes issued by us, Ensco International Incorporated and RCI, our wholly-owned subsidiaries. The tender offers expired on July 23, 2019, and we repurchased $951.8 million of our outstanding senior notes for an aggregate purchase price of $724.1 million. As a result of the transaction, we recognized a pre-tax gain from debt extinguishment of $194.1 million, net of discounts, premiums and debt issuance costs in other, net, in the consolidated statement of operations.

Concurrent with the issuance of the 2026 Notes in January 2018, we launched cash tender offers for up to $985.0 million aggregate principal amount of certain series of senior notes issued by us and Pride, our wholly-owned subsidiary, and as a result we repurchased $595.4 million of our senior notes. Subsequently, we issued a redemption notice for the remaining principal amount of the $55.0 million principal amount of the 8.50% senior notes due 2019 and repurchased $71.4 million principal amount of our senior notes due 2020. As a result of these transactions, we recognized a pre-tax loss from debt extinguishment of $19.0 million, net of discounts, premiums, debt issuance costs and commissions in other, net, in the consolidated statement of operations.

During 2017, we repurchased $194.1 million of our outstanding senior notes on the open market for an aggregate purchase price of $204.5 million with cash on hand and recognized an insignificant pre-tax gain, net of discounts, premiums and debt issuance costs.

Our tender offers and open market repurchases during the three-year period ended December 31, 2019 were as follows (in millions):
 
Aggregate Principal Amount Repurchased
 
Aggregate Repurchase Price(1)
Year Ended December 31, 2019
 
 
 
4.50% Senior notes due 2024
$
320.0

 
$
240.0

4.75% Senior notes due 2024
79.5

 
61.2

8.00% Senior notes due 2024
39.7

 
33.8

5.20% Senior notes due 2025
335.5

 
250.0

7.375% Senior notes due 2025
139.2

 
109.2

7.20% Senior notes due 2027
37.9

 
29.9

 
$
951.8

 
$
724.1

Year Ended December 31, 2018
 
 
 
8.50% Senior notes due 2019
$
237.6

 
$
256.8

6.875% Senior notes due 2020
328.0

 
354.7

4.70% Senior notes due 2021
156.2

 
159.7

 
$
721.8

 
$
771.2

Year Ended December 31, 2017
 
 
 
8.50% Senior notes due 2019
$
54.6

 
$
60.1

6.875% Senior notes due 2020
100.1

 
105.1

4.70% Senior notes due 2021
39.4

 
39.3

 
$
194.1

 
$
204.5



(1) 
Excludes accrued interest paid to holders of the repurchased senior notes.


121



Exchange Offers

During 2017, we completed exchange offers to exchange our outstanding 2019, 2020 and 2021 Notes for our 8% 2024 Notes and cash. The exchange offers resulted in the tender of $649.5 million aggregate principal amount of our outstanding notes that were settled and exchanged as follows (in millions):
 
Aggregate Principal Amount Repurchased
 
8% Senior Notes Due 2024 Consideration
 
Cash
Consideration
 
Total Consideration
8.50% Senior notes due 2019
$
145.8

 
$
81.6

 
$
81.7

 
$
163.3

6.875% Senior notes due 2020
129.8

 
69.3

 
69.4

 
138.7

4.70% Senior notes due 2021
373.9

 
181.1

 
181.4

 
362.5

 
$
649.5

 
$
332.0

 
$
332.5

 
$
664.5



During the year ended December 31, 2017, we recognized a pre-tax loss on the exchange offers of approximately $6.2 million.
 
Revolving Credit Facility

Effective upon closing of the Rowan Transaction, we amended our credit facility to, among other changes, increase the borrowing capacity. Previously, our credit facility had a borrowing capacity of $2.0 billion through September 2019 that declined to $1.3 billion through September 2020 and $1.2 billion through September 2022. Subsequent to the amendment, our borrowing capacity is $1.6 billion through September 2022. The credit agreement governing the Credit Facility includes an accordion feature allowing us to increase the future commitments up to an aggregate amount not to exceed $250.0 million.

Advances under the credit facility bear interest at Base Rate or LIBOR plus an applicable margin rate, depending on our credit ratings. We are required to pay a quarterly commitment fee on the undrawn portion of the $1.6 billion commitment, which is also based on our credit ratings.

On December 6, 2019, Moody's downgraded our corporate family rating from B3 to Caa1 and our senior unsecured notes from Caa1 to Caa2. Previously, in September 2019, Standard & Poor's downgraded our senior unsecured bonds from B to B- and our issuer rating from B- to CCC+. The applicable margin rates are 3.25% per annum for Base Rate advances and 4.25% per annum for LIBOR advances. The quarterly commitment fee is 0.75% per annum on the undrawn portion of the $1.6 billion commitment.

The credit facility requires us to maintain a total debt to total capitalization ratio that is less than or equal to 60% and to provide guarantees from certain of our rig-owning subsidiaries sufficient to meet certain guarantee coverage ratios. The credit facility also contains customary restrictive covenants, including, among others, prohibitions on creating, incurring or assuming certain debt and liens (subject to customary exceptions, including a permitted lien basket that permits us to raise secured debt up to the lesser of $1 billion or 10% of consolidated tangible net worth (as defined in the credit facility)); entering into certain merger arrangements; selling, leasing, transferring or otherwise disposing of all or substantially all of our assets; making a material change in the nature of the business; paying or distributing dividends on our ordinary shares (subject to certain exceptions, including the ability to pay a quarterly dividend of $0.01 per share); borrowings, if after giving effect to any such borrowings and the application of the proceeds thereof, the aggregate amount of available cash (as defined in the credit facility) would exceed $200 million; and entering into certain transactions with affiliates.

The credit facility also includes a covenant restricting our ability to repay indebtedness maturing after September 2022, which is the final maturity date of our credit facility. This covenant is subject to certain exceptions that permit us to manage our balance sheet, including the ability to make repayments of indebtedness (i) of acquired companies within 90 days of the completion of the acquisition or (ii) if, after giving effect to such repayments, available

122



cash is greater than $250 million and there are no amounts outstanding under the credit facility. The July 2019 tender offers discussed above were in compliance with these covenants.

As of December 31, 2019, we were in compliance in all material respects with our covenants under the credit facility. We expect to remain in compliance with our credit facility covenants during 2020. We had no amounts outstanding under the credit facility as of December 31, 2019 and 2018. As of January 31, 2020, we had $90 million of total outstanding borrowings under our credit facility.

Our access to credit and capital markets depends on the credit ratings assigned to our debt. As a result of rating actions by credit rating agencies, we no longer maintain an investment-grade status. Our current credit ratings, and any additional actual or anticipated downgrades in our credit ratings, could limit our available options when accessing credit and capital markets, or when restructuring or refinancing our debt. In addition, future financings or refinancings are likely to involve higher borrowing costs and require more restrictive terms and covenants, which may further restrict our operations.

Maturities

The descriptions of our senior notes above reflect the original principal amounts issued, which have subsequently changed as a result of our tenders, repurchases, exchanges, redemptions and new debt issuances such that the maturities of our debt were as follows (in millions):
Senior Notes
Original Principal
 
2016 Tenders, Repurchases and Equity Exchange
 
2017 Exchange Offers and Repurchases
 
2018 Tender Offers, Redemption and Debt Issuance
 
2019 Tender Offers, Redemption and Debt Issuance
 
Remaining Principal
6.875% due 2020
$
900.0

 
$
(219.2
)
 
$
(229.9
)
 
$
(328.0
)
 
$

 
$
122.9

4.70% due 2021
1,500.0

 
(817.0
)
 
(413.3
)
 
(156.2
)
 

 
113.5

4.875% due 2022 (1)

 

 

 

 
620.8

 
620.8

3.00% Exchangeable senior notes due 2024
849.5

 

 

 

 

 
849.5

4.50% due 2024
625.0

 
(1.7
)
 

 

 
(320.0
)
 
303.3

4.75% due 2024 (1)

 

 

 

 
318.6

 
318.6

8.00% due 2024

 

 
332.0

 

 
(39.7
)
 
292.3

5.20% due 2025
700.0

 
(30.7
)
 

 

 
(335.5
)
 
333.8

7.375% due 2025 (1)

 

 

 

 
360.8

 
360.8

7.75% due 2026

 

 

 
1,000.0

 

 
1,000.0

7.20% due 2027
150.0

 

 

 

 
(37.9
)
 
112.1

7.875% due 2040
300.0

 

 

 

 

 
300.0

5.40% due 2042 (1)

 

 

 

 
400.0

 
400.0

5.75% due 2044
1,025.0

 
(24.5
)
 

 

 

 
1,000.5

5.85% due 2044 (1)

 

 

 

 
400.0

 
400.0

Total
$
6,049.5


$
(1,093.1
)

$
(311.2
)

$
515.8


$
1,367.1

 
$
6,528.1



(1) 
These senior notes were acquired in the Rowan Transaction.

Interest Expense

Interest expense totaled $428.3 million, $282.7 million and $224.2 million for the years ended December 31, 2019, 2018 and 2017, respectively, which was net of capitalized interest of $20.9 million, $62.6 million and $72.5 million associated with newbuild rig construction and other capital projects.


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8.  DERIVATIVE INSTRUMENTS
   
Our functional currency is the U.S. dollar. As is customary in the oil and gas industry, a majority of our revenues are denominated in U.S. dollars; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than the U.S. dollar. These transactions are remeasured in U.S. dollars based on a combination of both current and historical exchange rates. We use derivatives to reduce our exposure to various market risks, primarily foreign currency exchange rate risk. We maintain a foreign currency exchange rate risk management strategy that utilizes derivatives to reduce our exposure to unanticipated fluctuations in earnings and cash flows caused by changes in foreign currency exchange rates. We mitigate our credit risk relating to the counterparties of our derivatives by transacting with multiple, high-quality financial institutions, thereby limiting exposure to individual counterparties, and by entering into International Swaps and Derivatives Association, Inc. (“ISDA”) Master Agreements, which include provisions for a legally enforceable master netting agreement, with our derivative counterparties. See "Note 16 - Supplemental Financial Information" for additional information on the mitigation of credit risk relating to counterparties of our derivatives. We do not enter into derivatives for trading or other speculative purposes.
 
All derivatives were recorded on our consolidated balance sheets at fair value. Derivatives subject to legally enforceable master netting agreements were not offset on our consolidated balance sheets. Accounting for the gains and losses resulting from changes in the fair value of derivatives depends on the use of the derivative and whether it qualifies for hedge accounting. See "Note 1 - Description of the Business and Summary of Significant Accounting Policies" for additional information on our accounting policy for derivatives and "Note 5 - Fair Value Measurements" for additional information on the fair value measurement of our derivatives.
 
As of December 31, 2019 and 2018, our consolidated balance sheets included net foreign currency derivative assets of $5.4 million and liabilities of $10.7 million, respectively.  All of our derivatives mature within the next 18 months.

Derivatives recorded at fair value on our consolidated balance sheets as of December 31, 2019 and 2018 consisted of the following (in millions):
 
Derivative Assets
 
Derivative Liabilities
 
2019
 
2018
 
2019
 
2018
Derivatives Designated as Hedging Instruments
 

 
 

 
 

 
 

Foreign currency forward contracts - current(1)
$
4.2

 
$
.2

 
$
.7

 
$
8.3

Foreign currency forward contracts - non-current(2)
.8

 

 

 
.4

 
5.0

 
.2

 
.7

 
8.7

Derivatives not Designated as Hedging Instruments
 

 
 

 
 

 
 

Foreign currency forward contracts - current(1)
1.3

 
.4

 
.2

 
2.6

Total
$
6.3

 
$
.6

 
$
.9

 
$
11.3


(1) 
Derivative assets and liabilities that have maturity dates equal to or less than 12 months from the respective balance sheet dates were included in other current assets and accrued liabilities and other, respectively, on our consolidated balance sheets.

(2) 
Derivative assets and liabilities that have maturity dates greater than 12 months from the respective balance sheet dates were included in other assets and other liabilities, respectively, on our consolidated balance sheets.

We utilize cash flow hedges to hedge forecasted foreign currency denominated transactions, primarily to reduce our exposure to foreign currency exchange rate risk associated with contract drilling expenses and capital expenditures denominated in various currencies.  As of December 31, 2019, we had cash flow hedges outstanding to exchange an aggregate $199.1 million for various foreign currencies, including $114.8 million for British pounds, $45.9 million

124



for Australian dollars, $15.9 million for euros, $10.9 million for Norwegian krone, $7.9 million for Singapore dollars and $3.7 million for Brazilian reals.

Gains and losses, net of tax, on derivatives designated as cash flow hedges included in our consolidated statements of operations and comprehensive loss for each of the years in the three-year period ended December 31, 2019 were as follows (in millions):
 
Gain (Loss) Recognized in Other Comprehensive
Income ("OCI")
on Derivatives
  (Effective Portion)  
 
(Gain) Loss Reclassified from
 AOCI into Income
(Effective Portion)(1)
 
Gain (Loss) Recognized
in Income on
Derivatives (Ineffective
Portion and Amount
Excluded from
Effectiveness Testing)(2)
 
2019
 
2018
 
2017
 
2019
 
2018
 
2017
 
2019
 
2018
 
2017
Interest rate lock contracts(3) 
$

 
$

 
$

 
$
1.9

 
$
.2

 
$
.2

 
$

 
$

 
$

Foreign currency forward contracts(4)
1.6

 
(9.7
)
 
8.5

 
6.4

 
(1.2
)
 
.2

 

 
(1.9
)
 
(.7
)
Total
$
1.6

 
$
(9.7
)
 
$
8.5

 
$
8.3

 
$
(1.0
)
 
$
.4

 
$

 
$
(1.9
)
 
$
(.7
)
 
(1)
Changes in the fair value of cash flow hedges are recorded in AOCI.  Amounts recorded in AOCI associated with cash flow hedges are subsequently reclassified into contract drilling, depreciation or interest expense as earnings are affected by the underlying hedged forecasted transaction.

(2) 
Gains and losses recognized in income for amounts excluded from effectiveness testing were included in other, net, in our consolidated statements of operations. As a result of our adoption of Update 2017-12 on January 1, 2019, ineffectiveness is no longer separately measured and recognized.

(3) 
Losses on interest rate lock derivatives reclassified from AOCI into income were included in interest expense, net, in our consolidated statements of operations.

(4) 
During the year ended December 31, 2019, $7.3 million of losses were reclassified from AOCI into contract drilling expense and $0.9 million of gains were reclassified from AOCI into depreciation expense in our consolidated statement of operations. During the year ended December 31, 2018, $400,000 of gains were reclassified from AOCI into contract drilling expense and $800,000 of gains were reclassified from AOCI into depreciation expense in our consolidated statement of operations. During the year ended December 31, 2017, $1.1 million of losses were reclassified from AOCI into contract drilling expense and $900,000 of gains were reclassified from AOCI into depreciation expense in our consolidated statement of operations.

We have net assets and liabilities denominated in numerous foreign currencies and use various methods to manage our exposure to foreign currency exchange rate risk. We predominantly structure our drilling contracts in U.S. dollars, which significantly reduces the portion of our cash flows and assets denominated in foreign currencies. We occasionally enter into derivatives that hedge the fair value of recognized foreign currency denominated assets or liabilities but do not designate such derivatives as hedging instruments. In these situations, a natural hedging relationship generally exists whereby changes in the fair value of the derivatives offset changes in the fair value of the underlying hedged items. As of December 31, 2019, we held derivatives not designated as hedging instruments to exchange an aggregate $47.1 million for various foreign currencies, including $15.4 million for British pounds, $6.6 million for Israeli New shekel, $5.9 million for Norwegian krone, $4.9 million for Nigerian naira, $4.5 million for Thai baht, $4.3 million for Australian dollars and $5.5 million for other currencies.

Net losses of $6.4 million and $11.8 million and gains of $10.0 million associated with our derivatives not designated as hedging instruments were included in other, net, in our consolidated statements of operations for the years ended December 31, 2019, 2018 and 2017, respectively.


125



As of December 31, 2019, the estimated amount of net gains associated with derivatives, net of tax, that will be reclassified to earnings during the next 12 months was as follows (in millions):

Net unrealized losses to be reclassified to contract drilling expense
 
$
3.4

Net realized gains to be reclassified to depreciation expense
 
.8

Net losses to be reclassified to earnings
 
$
4.2




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9.  SHAREHOLDERS' EQUITY
 
Activity in our various shareholders' equity accounts for each of the years in the three-year period ended December 31, 2019 was as follows (in millions):
 
 Shares 
 
Par Value
 
Additional
Paid-in
Capital
 
Retained
Earnings
 
AOCI 
 
Treasury
Shares
 
Non-controlling
Interest
BALANCE, December 31, 2016
77.6

 
$
31.1

 
$
6,402.2

 
$
1,864.1

 
$
19.0

 
$
(65.8
)
 
$
4.4

Net loss

 

 

 
(303.7
)
 

 

 
(.5
)
Dividends paid ($0.16 per share)

 

 

 
(13.6
)
 

 

 

Cumulative-effect reduction from adoption of ASU 2016-16
 
 
 
 
 
 
(14.1
)
 
 
 
 
 
 
Distributions to noncontrolling interests

 

 

 

 

 

 
(6.0
)
Equity issuance in connection with Atwood Merger
33.1

 
13.2

 
757.5

 

 

 

 

Shares issued under share-based compensation plans, net
1.1

 
.5

 
(.4
)
 

 

 
(1.3
)
 

Repurchase of shares

 

 

 

 

 
(1.9
)
 

Share-based compensation cost

 

 
35.7

 

 

 

 

Net other comprehensive income

 

 

 

 
9.6

 

 

BALANCE, December 31, 2017
111.8

 
44.8


7,195.0


1,532.7


28.6


(69.0
)

(2.1
)
Net loss

 

 

 
(639.7
)
 

 

 
3.1

Dividends paid ($0.16 per share)

 

 

 
(18.0
)
 

 

 

Cumulative-effect reduction from adoption of ASU 2018-02

 

 

 
(.8
)
 
.8

 

 

Shares issued under share-based compensation plans, net
3.4

 
1.4

 
(.6
)
 

 

 
(1.3
)
 

Distributions to noncontrolling interests

 

 

 

 

 

 
(3.6
)
Repurchase of shares

 

 

 

 

 
(1.9
)
 

Share-based compensation cost

 

 
30.6

 

 

 

 

Net other comprehensive income

 

 

 

 
(11.2
)
 

 

BALANCE, December 31, 2018
115.2

 
46.2


7,225.0


874.2


18.2


(72.2
)

(2.6
)
Net loss

 

 

 
(198.0
)
 

 

 
5.8

Dividends paid ($0.04 per share)

 

 

 
(4.5
)
 

 

 

Equity issuance in connection with the Rowan Transaction
88.0

 
35.2

 
1,367.5

 

 

 
.1

 

Shares issued under share-based compensation plans, net
2.7

 
1.1

 
(1.3
)
 

 

 
(.7
)
 

Repurchase of shares

 

 

 

 

 
(4.5
)
 

Share-based compensation cost

 

 
37.2

 

 

 

 

Equity issuance cost

 

 
(.6
)
 

 

 

 

Net changes in pension and other postretirement benefits

 

 

 

 
(21.7
)
 

 

Distributions to noncontrolling interests

 

 

 

 

 

 
(4.5
)
Net other comprehensive income

 

 

 

 
9.7

 

 

BALANCE, December 31, 2019
205.9

 
$
82.5


$
8,627.8


$
671.7


$
6.2


$
(77.3
)

$
(1.3
)

    
In connection with the Rowan Transaction on April 11, 2019, we issued 88.3 million Class A ordinary shares with an aggregate value of $1.4 billion. See Note 3 for additional information.


127



On April 11, 2019, we completed our combination with Rowan and effected the Reverse Stock Split. All share and per-share amounts in these consolidated financial statements have been retrospectively adjusted to reflect the Reverse Stock Split.

In October 2017, as a result of our acquisition of Atwood Oceanics, Inc. (the "Atwood Merger"), we issued 33.1 million of our Class A Ordinary shares, representing total equity consideration of $770.7 million based on a closing price of $5.83 per Class A ordinary share on October 5, 2017, the last trading day before the Merger Date.

As a U.K. company governed in part by the U.K. Companies Act 2006, we cannot issue new shares (other than in limited circumstances) without being authorized by our shareholders. At our 2019 annual general meeting, our shareholders authorized the allotment of 67.6 million Class A ordinary shares (or 135.3 million Class A ordinary shares in connection with an offer by way of a rights issue or other similar issue), subject to the completion of the Rowan Transaction.

Under English law, we are only able to declare dividends and return funds to our shareholders out of the accumulated distributable reserves on our statutory balance sheet. The declaration and amount of future dividends is at the discretion of our Board of Directors and will depend on our profitability, liquidity, financial condition, market outlook, reinvestment opportunities, capital requirements and other factors and restrictions our Board of Directors deems relevant. There can be no assurance that we will pay a dividend in the future.
    Our shareholders approved a share repurchase program at our annual shareholder meeting held in May 2018. Subject to certain provisions under English law, including the requirement of Valaris plc to have sufficient distributable reserves, we may repurchase shares up to a maximum of $500.0 million in the aggregate from one or more financial intermediaries under the program, but in no case more than 16.3 million shares. The program terminates in May 2023. As of December 31, 2019, there had been no share repurchases under this program.
    
10.  SHARE BASED COMPENSATION
 
In May 2018, our shareholders approved the 2018 Long-Term Incentive Plan (the "2018 LTIP") effective January 1, 2018, to provide for the issuance of non-vested share awards, share option awards and performance awards (collectively "awards"). The 2018 LTIP is similar to and replaces the Company's previously adopted 2012 Long-Term Incentive Plan (the “2012 LTIP”). No further awards will be granted under the 2012 LTIP. Under the 2018 LTIP, 14.8 million shares were reserved for issuance as awards to officers, non-employee directors and key employees who are in a position to contribute materially to our growth, development and long-term success. As of December 31, 2019, there were 2.5 million shares available for issuance as awards under the 2018 LTIP. Awards may be satisfied by newly issued shares, including shares held by a subsidiary or affiliated entity, or by delivery of shares held in an affiliated employee benefit trust at the Company's discretion.

In connection with the Rowan Transaction, we assumed the Amended and Restated 2013 Rowan Companies plc Incentive Plan (the "Rowan LTIP") and the non-vested share unit awards, options and share appreciation rights outstanding thereunder. As of December 31, 2019, there were 2.3 million shares remaining available for future issuance as awards under the Rowan LTIP which may be granted to employees and other service providers who were not employed or engaged with Valaris prior to the Rowan Transaction.

In connection with the Atwood Merger, we assumed Atwood’s Amended and Restated 2007 Long-Term Incentive Plan (the “Atwood LTIP”, and together with the 2018 LTIP and the Rowan LTIP, the "LTIP Plans") and the options outstanding thereunder. As of December 31, 2019, there were 100,000 shares remaining available for future issuance as awards under the Atwood LTIP, which may be granted to employees and other service providers who were not employed or engaged with Valaris prior to the Atwood Merger.


128



Non-Vested Share Awards, Cash-Settled Awards and Non-employee Director Deferred Awards
 
Grants of share awards and share units (collectively "share awards") and share units to be settled in cash ("cash-settled awards"), generally vest at rates of 20% or 33% per year, as determined by a committee of the Board of Directors at the time of grant. Additionally, non-employee directors may annually elect to receive deferred share awards. Deferred share awards vest at the earlier of the first anniversary of the grant date or the next annual meeting of shareholders following the grant but are not settled until the director terminates service from the Board. Deferred share awards are settled in cash, shares or a combination thereof at the discretion of the Compensation Committee.

During 2019, no cash-settled awards were granted while 4.5 million share unit awards were granted to our employees and non-employee directors pursuant to the LTIP Plans. Our non-vested share awards have voting and dividend rights effective on the date of grant, and our non-vested share units have dividend rights effective on the date of grant. Compensation expense for share awards is measured at fair value on the date of grant and recognized on a straight-line basis over the requisite service period (usually the vesting period). Compensation expense for cash-settled awards is remeasured each quarter with a cumulative adjustment to compensation cost during the period based on changes in our share price. Our compensation cost is reduced for forfeited awards in the period in which the forfeitures occur.

The following table summarizes share award and cash-settled award compensation expense recognized during each of the years in the three-year period ended December 31, 2019 (in millions):
 
2019
 
2018
 
2017
Contract drilling
$
22.1

 
$
18.9

 
$
18.3

General and administrative
17.4

 
14.5

 
14.5

 
39.5

 
33.4

 
32.8

Tax benefit
(2.5
)
 
(2.8
)
 
(4.8
)
Total
$
37.0

 
$
30.6

 
$
28.0



The following table summarizes the value of share awards and cash-settled awards granted and vested during each of the years in the three-year period ended December 31, 2019:
 
Share Awards
 
Cash-Settled Awards
 
2019
 
2018
 
2017
 
2019
 
2018
 
2017
Weighted-average grant-date fair value of share awards granted (per share)
$
11.50

 
$
24.62


$
31.48

 
$

 
$
21.35

 
$
25.08

Total fair value of share awards vested during the period (in millions)
$
17.7

 
$
7.5


$
8.2

 
$
3.5

 
$
9.9

 
$
3.9


    

129



The following table summarizes share awards and cash-settled awards activity for the year ended December 31, 2019 (shares in thousands):
 
Share Awards
 
Cash-settled Awards
 
Awards
 
Weighted-Average
Grant-Date
Fair Value
 
Awards
 
Weighted-Average
Grant-Date
Fair Value
Share awards and cash-settled awards as of December 31, 2018
2,017

 
$
31.36

 
1,279

 
$
29.20

Granted
4,460

 
11.50

 

 

Rowan share awards assumed
2,329

 
15.88

 

 

Vested
(1,519
)
 
10.53

 
(453
)
 
7.97

Forfeited
(854
)
 
8.87

 
(129
)
 
11.58

Share awards and cash-settled awards as of December 31, 2019
6,433

 
$
19.89

 
697

 
$
46.28



As of December 31, 2019, there was $115.9 million of total unrecognized compensation cost related to share awards, which is expected to be recognized over a weighted-average period of 1.7 years.

Share Appreciation Rights

Share Appreciation Rights ("SARs") granted to employees generally become exercisable in 33% increments over a three-year period and, to the extent not exercised, expire on the tenth anniversary of the date of grant. The exercise price of SARs granted under the Rowan LTIP equals the excess of the market value of the underlying shares on the date of exercise over the market value of the shares on date of grant multiplied by the number of shares covered by the SAR. The Company intends to share-settle any exercises of SARs and has therefore accounted for SARs as equity awards. As of December 31, 2019, SARs granted to purchase 530,923 shares with a weighted-average exercise price of $50.70 were outstanding under the Rowan LTIP. No SARs have been granted since 2010 under the Rowan LTIP, and there was no unrecognized compensation cost related to SARs as of December 31, 2019.

Share Option Awards

Share option awards ("options") granted to employees generally become exercisable in 25% increments over a four-year period or 33% increments over a three-year period or 100% after a four - year period and, to the extent not exercised, expire on either the seventh or tenth anniversary of the date of grant. The exercise price of options granted under the 2018 LTIP equals the market value of the underlying shares on the date of grant. As of December 31, 2019, options granted to purchase 375,701 shares with a weighted-average exercise price of $52.77 were outstanding under the Company LTIPs. Excluding options assumed under the Atwood LTIP, no options have been granted since 2011, and there was no unrecognized compensation cost related to options as of December 31, 2019.

Performance Awards

Under the Company LTIPs, performance awards may be issued to our senior executive officers. The 2019 performance awards are subject to achievement of specified performance goals based on both relative and absolute total shareholder return ("TSR"), while the 2017 and 2018 performance awards are subject to achievement of specified performance goals based on relative TSR and relative return on capital employed ("ROCE") as compared to a specified peer group. The performance goals are determined by a committee or subcommittee of the Board of Directors. Awards are payable in either Valaris shares or cash upon attainment of relative TSR and ROCE performance goals. Performance awards granted since 2017 are payable in cash.

Performance awards generally vest at the end of a three-year measurement period based on attainment of performance goals. Our performance awards granted during 2017, 2018 and 2019 are classified as liability awards, all

130



with compensation expense recognized over the requisite service period. The estimated probable outcome of attainment of the specified performance goals is based primarily on relative performance over the requisite performance period. Any subsequent changes in this estimate are recognized as a cumulative adjustment to compensation cost in the period in which the change in estimate occurs.
    
The aggregate grant-date fair value of performance awards granted during 2019, 2018 and 2017 totaled $6.7 million. The aggregate fair value of performance awards vested during 2019, 2018 and 2017 totaled $2.2 million, $0.7 million and $2.9 million, respectively.

During the years ended December 31, 2019, 2018 and 2017, we recognized $3.2 million, $8.2 million and $8.4 million of compensation expense for performance awards, respectively, which was included in general and administrative expense in our consolidated statements of operations.  As of December 31, 2019, there was $0.8 million of total unrecognized compensation cost related to unvested performance awards, which is expected to be recognized over a weighted-average period of 1.1 years.

Savings Plans

We have savings plans, (the Ensco Savings Plan, the Ensco Multinational Savings Plan, the Ensco Limited Retirement Plan, the Rowan Companies, Inc. Savings & Investment Plan (the "Rowan Savings Plan"), the RDIS International Savings Plan and the Rowan Drilling UK Pension Scheme), which cover eligible employees as defined within each plan.  The Ensco Savings Plan and the Rowan Savings Plan include a 401(k) savings plan feature, which allows eligible employees to make tax-deferred contributions to the plans.  The Ensco Limited Retirement Plan and the Rowan Drilling UK Pension Scheme also allows eligible employees to make tax-deferred contributions to the plan. Contributions made to the Ensco Multinational Savings Plan and the RDIS International Savings Plan may or may not qualify for tax deferral based on each plan participant's local tax requirements.
 
We generally make matching cash contributions to the plans.  The legacy Ensco plans match 100% of the amount contributed by the employee up to a maximum of 5% of eligible salary, where the legacy Rowan plans also provide up to a 5% match of eligible salary; however, depending on the plan and the tier, the match percentage could vary. Matching contributions totaled $18.7 million, $14.4 million and $12.2 million for the years ended December 31, 2019, 2018 and 2017, respectively.  Any additional discretionary contributions made into the plans require approval of the Board of Directors and are generally paid in cash. As of January 1, 2019, the plans were modified such that all previous, current and future employer contributions become 100% vested. We have 1.0 million shares reserved for issuance as matching contributions under the Ensco Savings Plan.


131



Note 11 -     Pension and Other Post-retirement Benefits

Prior to the Rowan Transaction, Rowan established various defined-benefit pension plans and a post-retirement health and life insurance plan that provide benefits upon retirement for certain full-time employees. The defined-benefit pension plans include: (1) the Rowan Pension Plan; (2) Restoration Plan of Rowan Companies, Inc. (the “Rowan SERP”); (3) the Norway Onshore Plan; and (4) the Norway Offshore Plan. The Retiree Life & Medical Supplemental Plan of Rowan Companies, Inc. (the “Retiree Medical Plan”) provides post-retirement health and life insurance benefits. On November 27, 2017, Rowan purchased annuities to cover post-65 retiree medical benefits for current retirees as of the purchase date. The annuity purchase settled post-65 medical benefits (i.e., Health Reimbursement Account, or “HRA”, amounts) for affected participants, with the insurer taking responsibility for all benefit payments on and after January 1, 2019.
 
As a result of the Rowan Transaction, we assumed these plans and obligations, which were remeasured as of the Transaction Date. Each of the plans has a benefit obligation that exceeds the fair value of plan assets. As of the Transaction Date, the net projected benefit obligations totaled $239.3 million, of which $19.2 million was classified as current. The current and non-current portions of the net benefit obligations are included in accrued liabilities and other liabilities in our consolidated balance sheet, respectively. The most significant of the assumed plans is the Rowan Pension Plan, which had a net projected benefit obligation of $202.1 million. Prior to the Transaction Date, Rowan amended the Rowan Pension Plan to freeze the plan as to any future benefit accruals. As a result, eligible employees no longer receive pay credits in the pension plan and newly hired employees are not eligible to participate in the pension plan.

132



The following table presents the changes in benefit obligations and plan assets for the year ended December 31, 2019 and the funded status and weighted-average assumptions used to determine the benefit obligation at year end (dollars in millions):
 
 
2019
 
 
Pension Benefits
 
Other Benefits
 
Total
Projected benefit obligation:
 
 
 
 
 
 
Balance, April 11
 
$
800.1

 
$
15.9

 
$
816.0

   Interest cost
 
21.3

 
0.4

 
21.7

   Service cost
 
1.5

 

 
1.5

   Actuarial loss
 
43.8

 
0.2

 
44.0

   Benefits paid
 
(34.1
)
 
(0.4
)
 
(34.5
)
   Foreign currency adjustments
 
(0.2
)
 

 
(0.2
)
Balance, December 31
 
$
832.4

 
$
16.1

 
$
848.5

 
 
 
 
 
 
 
Plan assets
 
 
 
 
 
 
Fair value, April 11
 
$
576.8

 
$

 
$
576.8

   Actual return
 
43.6

 

 
43.6

   Employer contributions
 
12.8

 

 
12.8

   Benefits paid
 
(34.1
)
 

 
(34.1
)
   Foreign currency adjustments
 
(0.2
)
 

 
(0.2
)
Fair value, December 31
 
$
598.9

 

 
$
598.9

Net benefit liabilities
 
$
233.5


$
16.1


$
249.6

 
 
 
 
 
 
 
Amounts recognized in consolidated balance sheet:
 
 
 
 
 
 
Accrued liabilities
 
$
(1.4
)
 
$
(1.5
)
 
$
(2.9
)
Other liabilities (long-term)
 
(232.1
)
 
(14.6
)
 
(246.7
)
Net benefit liabilities
 
$
(233.5
)

$
(16.1
)

$
(249.6
)
 
 
 
 
 
 
 
Accumulated contributions in excess of (less than) net periodic benefit cost
 
$
(206.2
)
 
$
(15.9
)
 
$
(222.1
)
 
 
 
 
 
 
 
Amounts not yet reflected in net periodic benefit cost:
 
 
 
 
 
 
Actuarial loss
 
$
(27.3
)
 
$
(0.2
)
 
$
(27.5
)
Total accumulated other comprehensive loss
 
(27.3
)
 
(0.2
)
 
(27.5
)
Net benefit liabilities
 
$
(233.5
)

$
(16.1
)

$
(249.6
)
 
 
 
 
 
 
 
Weighted-average assumptions:
 
 
 
 
 
 
Discount rate
 
3.16
%
 
3.06
%
 
 
Rate of compensation increase
 
%
 
%
 
 


The projected benefit obligations for pension benefits in the preceding table reflect the actuarial present value of benefits accrued based on services rendered to date and include the estimated effect of future salary increases.





133



The accumulated benefit obligations, which are presented below for all plans in the aggregate at December 31, 2019, are based on services rendered to date, but exclude the effect of future salary increases (in millions):
 
 
2019
Accumulated benefit obligation
 
$
844.3



The components of net periodic pension cost and the weighted-average assumptions used to determine net periodic pension cost were as follows (dollars in millions):
 
 
April 11, 2019 - December 31, 2019
Service cost (1)
 
$
1.5

Interest cost (2)
 
21.3

Expected return on plan assets (2)
 
(27.1
)
     Net periodic pension cost (benefit)
 
$
(4.3
)
Discount rate
 
3.82
%

(1) 
Included in contract drilling and general and administrative expense in our consolidated statements of operations.
(2) Included in other, net, in our consolidated statements of operations.

The pension plans' investment objectives for fund assets are: to achieve over the life of the plans a return equal to the plans' expected investment return or the inflation rate plus 3%, whichever is greater, to invest assets in a manner such that contributions are minimized and future assets are available to fund liabilities, to maintain liquidity sufficient to pay benefits when due, and to diversify among asset classes so that assets earn a reasonable return with an acceptable level of risk. The plans employ several active managers with proven long-term records in their specific investment discipline.

Target allocations among asset categories and the fair value of each category of plan assets as of December 31, 2019, classified by level within the US GAAP fair value hierarchy are presented below. The plans will reallocate assets in accordance with the allocation targets, after giving consideration to the expected level of cash required to pay current benefits and plan expenses (dollars in millions):

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Target range
 
Total
 
Quoted prices in active markets for identical assets (Level 1)
 
Significant observable inputs (Level 2)
 
Significant unobservable inputs (Level 3)
December 31, 2019
 
 
 
 
 
 
 
 
 
 
Equities:
 
53% to 69%
 
 
 
 
 
 
 
 
   U.S. large cap
 
22% to 28%
 
$
148.9

 
$

 
$
148.9

 
$

   U.S. small cap
 
4% to 10%
 
41.1

 

 
41.1

 

   International all cap
 
21% to 29%
 
152.4

 

 
152.4

 

   International small cap
 
2% to 8%
 
34.7

 

 
34.7

 

Real estate equities
 
0% to 13%
 
54.9

 

 
54.9

 

Fixed income:
 
25% to 35%
 

 
 
 


 


   Cash and equivalents
 
0% to 10%
 
6.5

 
6.5

 

 

Aggregate
 
9% to 19%
 
76.7

 

 
76.7

 

   Core plus
 
9% to 19%
 
77.6

 
77.6

 

 

Group annuity contracts
 
 
 
6.1

 

 
6.1

 

    Total
 
 
 
$
598.9

 
$
84.1

 
$
514.8

 
$



    Assets in the U.S. equities category include investments in common and preferred stocks (and equivalents such as American Depository Receipts and convertible bonds) and may be held through separate accounts, commingled funds or an institutional mutual fund. Assets in the international equities category include investments in a broad range of international equity securities, including both developed and emerging markets, and may be held through a commingled or institutional mutual fund. The real estate category includes investments in pooled and commingled funds whose objectives are diversified equity investments in income-producing properties. Each real estate fund is intended to provide broad exposure to the real estate market by property type, geographic location and size and may invest internationally. Securities in both the aggregate and core plus fixed income categories include U.S. government, corporate, mortgage- and asset-backed securities and Yankee bonds, and both categories target an average credit rating of “A” or better at all times. Individual securities in the aggregate fixed income category must be investment grade or above at the time of purchase, whereas securities in the core plus category may have a rating of “B” or above. Additionally, the core plus category may invest in non-U.S. securities. Assets in the aggregate and core plus fixed income categories are held primarily through a commingled fund and an institutional mutual fund, respectively. Group annuity contracts are invested in a combination of equity, real estate, bond and other investments in connection with a pension plan in Norway.

The following is a description of the valuation methodologies used for the pension plan assets as of December 31, 2019:

Fair values of all U.S. equity securities, the international all cap equity securities and aggregate fixed income securities categorized as Level 2 were held in commingled funds which were valued daily based on a net asset value.
Fair value of international small cap equity securities categorized as Level 2 were held in a limited partnership fund which was valued monthly based on a net asset value.
The real estate equities categorized as Level 2 were held in two accounts (a commingled fund and a limited partnership). The assets in the commingled fund were valued monthly based on a net asset value and the assets in the limited partnership were valued quarterly based on a net asset value.
Cash and equivalents categorized as Level 1 were valued at cost, which approximates fair value.

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Fair value of mutual fund investments in core plus fixed income securities categorized as Level 1 were based on quoted market prices which represent the net asset value of shares held.
    
To develop the expected long-term rate of return on assets assumption, we considered the current level of expected returns on risk-free investments (primarily government bonds), the historical level of the risk premium associated with the plans’ other asset classes and the expectations for future returns of each asset class. The expected return for each asset class was then weighted based upon the current asset allocation to develop the expected long-term rate of return on assets assumption for the plans, which was 6.48% at December 31, 2019.
    
We currently expect to contribute approximately $35.7 million to our pension plans in 2020 and to directly pay other post-retirement benefits of approximately $1.5 million.

Estimated future annual benefit payments from plan assets are presented below. Such amounts are based on existing benefit formulas and include the effect of future service (in millions):
 
 
Pension Benefits
 
Other Post-Retirement Benefits
Year ended December 31,
 
 
 
 
2020
 
$
45.0

 
$
1.5

2021
 
45.0

 
1.4

2022
 
44.6

 
1.3

2023
 
44.2

 
1.3

2024
 
43.9

 
1.3

2025 through 2029
 
213.6

 
5.3


12.  INCOME TAXES

We generated profits of $39.0 million, losses of $115.1 million and profits of $6.3 million from continuing operations before income taxes in the U.S. and losses of $102.8 million, $423.8 million and $202.3 million from continuing operations before income taxes in non-U.S. jurisdictions for the years ended December 31, 2019, 2018 and 2017, respectively.

The following table summarizes components of our provision for income taxes from continuing operations for each of the years in the three-year period ended December 31, 2019 (in millions):
 
2019
 
2018
 
2017
Current income tax expense (benefit):
 

 
 

 
 

U.S.
$
31.3

 
$
(19.9
)
 
$
(2.2
)
Non-U.S.
73.2

 
52.9

 
56.4

 
104.5

 
33.0

 
54.2

Deferred income tax expense:
 

 
 

 
 

U.S.
19.7

 
52.9

 
36.0

Non-U.S.
4.2

 
3.7

 
19.0

 
23.9

 
56.6

 
55.0

Total income tax expense
$
128.4

 
$
89.6

 
$
109.2


    

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U.S. Tax Reform

U.S. tax reform was enacted on December 22, 2017 and introduced significant changes to U.S. income tax law, including a reduction in the statutory income tax rate from 35% to 21% effective January 1, 2018, a one-time transition tax on deemed repatriation of deferred foreign income, a base erosion anti-abuse tax that effectively imposes a minimum tax on certain payments to non-U.S. affiliates, new and revised rules relating to the current taxation of certain income of foreign subsidiaries and revised rules associated with limitations on the deduction of interest.

Due to the timing of the enactment of U.S. tax reform and the complexity involved in applying its provisions, we made reasonable estimates of its effects and recorded such amounts in our consolidated financial statements as of December 31, 2017 on a provisional basis. Throughout 2018, we continued to analyze applicable information and data, interpret rules and guidance issued by the U.S. Treasury Department and Internal Revenue Service, and make adjustments to the provisional amounts as provided for in Staff Accounting Bulletin No. 118. The U.S. Treasury Department continued finalizing rules associated with U.S. tax reform during 2018 and 2019.

During 2019, we recognized a tax expense of $13.8 million associated with final rules issued related to U.S. tax reform. During 2018, we recognized a tax benefit of $11.7 million associated with the one-time transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries. We recognized a net tax expense of $16.5 million during 2017 in connection with enactment of U.S. tax reform, consisting of a $38.5 million tax expense associated with the one-time transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries, a $17.3 million tax expense associated with revisions to rules over the taxation of income of foreign subsidiaries, a $20.0 million tax benefit resulting from the re-measurement of our deferred tax assets and liabilities as of December 31, 2017 to reflect the reduced tax rate and a $19.3 million tax benefit resulting from adjustments to the valuation allowance on deferred tax assets.

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Deferred Taxes

The following table summarizes significant components of deferred income tax assets and liabilities as of December 31, 2019 and 2018 (in millions):
 
 
2019
 
2018
Deferred tax assets:
 
 
 
 

Net operating loss carryforwards
 
$
1,546.7

 
$
148.4

Net capital loss carryforwards
 
998.0

 

Foreign tax credits
 
142.9

 
123.6

Interest limitation carryforwards
 
41.5

 
40.2

Premiums on long-term debt
 

 
23.8

Employee benefits, including share-based compensation
 
73.9

 
15.4

Deferred revenue
 
0.1

 
10.3

Other
 
11.6

 
14.5

Total deferred tax assets
 
2,814.7

 
376.2

Valuation allowance
 
(2,588.7
)
 
(316.0
)
Net deferred tax assets
 
226.0

 
60.2

Deferred tax liabilities:
 
 

 
 

Property and equipment
 
(156.0
)
 
(54.5
)
Net discounts on long-term debt
 
(49.5
)
 

Deferred U.S. tax on foreign income
 
(36.7
)
 
(31.5
)
Other
 
(23.7
)
 
(9.0
)
Total deferred tax liabilities
 
(265.9
)
 
(95.0
)
Net deferred tax asset (liability)
 
$
(39.9
)
 
$
(34.8
)

     
The realization of substantially all of our deferred tax assets is dependent upon generating sufficient taxable income during future periods in various jurisdictions in which we operate. Realization of certain of our deferred tax assets is not assured. We recognize a valuation allowance for deferred tax assets when it is more-likely-than-not that the benefit from the deferred tax asset will not be realized. The amount of deferred tax assets considered realizable could increase or decrease in the near-term if our estimates of future taxable income change.

As of December 31, 2019, we had deferred tax assets of $142.9 million for U.S. foreign tax credits (“FTCs”), $1.5 billion related to $6.4 billion of net operating loss (“NOL”) carryforwards and $41.5 million for U.S. interest limitation carryforwards, which can be used to reduce our income taxes payable in future years.  The FTCs expire between 2022 and 2029.  NOL carryforwards, which were generated in various jurisdictions worldwide, include $5.6 billion that do not expire and $773.0 million that will expire, if not utilized, between 2020 and 2037. Deferred tax assets for NOL carryforwards at December 31, 2019 includes $1.3 billion acquired in the Rowan Transaction, substantially all of which pertains to NOL in Luxembourg. U.S. interest limitation carryforwards do not expire. Due to the uncertainty of realization, we have a $1.5 billion valuation allowance on FTC, NOL carryforwards and U.S. interest limitation carryforwards.

During 2019, we completed certain restructuring transactions that generated substantial U.S. capital gains and losses. As of December 31, 2019, we had recognized a deferred tax asset of $998 million associated with the net capital loss arising from these transactions. Based on our current assessment, this deferred tax asset is subject to a full valuation allowance because we more-likely-than-not will be unable to realize a future benefit from it.
 
    

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Effective Tax Rate

Valaris plc, our parent company, is domiciled and resident in the U.K. Our subsidiaries conduct operations and earn income in numerous countries and are subject to the laws of taxing jurisdictions within those countries. The income of our non-U.K. subsidiaries is generally not subject to U.K. taxation. Income tax rates imposed in the tax jurisdictions in which our subsidiaries conduct operations vary, as does the tax base to which the rates are applied. In some cases, tax rates may be applicable to gross revenues, statutory or negotiated deemed profits or other bases utilized under local tax laws, rather than to net income.

Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. As a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in profitability levels and changes in tax laws, our annual effective income tax rate may vary substantially from one reporting period to another. In periods of declining profitability, our income tax expense may not decline proportionally with income, which could result in higher effective income tax rates. Further, we will continue to incur income tax expense in periods in which we operate at a loss.

Our consolidated effective income tax rate on continuing operations for each of the years in the three-year period ended December 31, 2019, differs from the U.K. statutory income tax rate as follows:
 
2019
 
2018
 
2017
U.K. statutory income tax rate
19.0
 %
 
19.0
 %
 
19.2
 %
Non-U.K. taxes
(280.9
)
 
(18.0
)
 
(40.4
)
Bargain purchase gain
189.7

 
(.2
)
 
13.8

Valuation allowance
(145.1
)
 
(16.9
)
 
(18.0
)
Debt repurchases
48.7

 
(1.6
)
 
(2.8
)
Asset impairments
(31.0
)
 
(1.4
)
 
(17.1
)
U.S. tax reform
(21.6
)
 
2.2

 
(8.4
)
Restructuring transaction
7.9

 
1.7

 

Other
12.0

 
(1.4
)
 
(2.0
)
Effective income tax rate
(201.3
)%
 
(16.6
)%
 
(55.7
)%


Our 2019 consolidated effective income tax rate includes $2.3 million associated with the impact of various discrete tax items, including $28.3 million of tax expense associated with final rules related to U.S. tax reform, gains on repurchase of debt and settlement proceeds, partially offset by $26.0 million of tax benefit related to restructuring transactions, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and other resolutions of prior year tax matters and rig sales.

Our 2018 consolidated effective income tax includes the impact of various discrete tax items, including $46.0 million of tax benefit associated with the utilization of foreign tax credits subject to a valuation allowance, the transition tax on deemed repatriation of the deferred foreign income of our U.S. subsidiaries and a restructuring transaction, partially offset by $21.0 million of tax expense related to recovery of certain costs associated with an ongoing legal matter, repurchase and redemption of senior notes, unrecognized tax benefits associated with tax positions taken in prior years and rig sales.

Our 2017 consolidated effective income tax rate includes $32.2 million associated with the impact of various discrete tax items, including $16.5 million of tax expense associated with U.S. tax reform and $15.7 million of tax expense associated with the exchange offers and debt repurchases, rig sales, a restructuring transaction, settlement of a previously disclosed legal contingency, the effective settlement of a liability for unrecognized tax benefits associated with a tax position taken in prior years and other resolutions of prior year tax matters.

139




Excluding the impact of the aforementioned discrete tax items, our consolidated effective income tax rates for the years ended December 31, 2019, 2018 and 2017 were (14.6)%, (24.8)% and (96.0)%. The changes in our consolidated effective income tax rate, excluding discrete tax items, during the three-year period result primarily from U.S. tax reform and changes in the relative components of our earnings from the various taxing jurisdictions in which our drilling rigs are operated and/or owned and differences in tax rates in such taxing jurisdictions.

As discussed in Note 7, on February 3, 2020, Rowan and RCI transferred substantially all their assets and liabilities to Valaris plc and Valaris plc became the obligor on the Rowan Notes. We expect to recognize a deferred tax benefit ranging from $40 million to $60 million during the first quarter of 2020 in connection with this transaction.

Unrecognized Tax Benefits

Our tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than 50% likely of being realized upon effective settlement with a taxing authority that has full knowledge of all relevant information.  As of December 31, 2019, we had $296.7 million of unrecognized tax benefits, of which $264.2 million was included in other liabilities on our consolidated balance sheet and the remaining $32.5 million, which is associated with a tax position taken in tax years with NOL carryforwards, was presented as a reduction of deferred tax assets. As of December 31, 2018, we had $143.0 million of unrecognized tax benefits, of which $136.5 million was included in other liabilities on our consolidated balance sheet and the remaining $6.5 million, which is associated with a tax position taken in tax years with NOL carryforwards, was presented as a reduction of deferred tax assets. If recognized, $253.9 million of the $296.7 million unrecognized tax benefits as of December 31, 2019 would impact our consolidated effective income tax rate. A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, 2019 and 2018 is as follows (in millions):
 
 
2019
 
2018
Balance, beginning of year
 
$
143.0

 
$
147.6

  Increases in unrecognized tax benefits as a result of the Rowan Transaction
 
149.9

 

   Increases in unrecognized tax benefits as a result
      of tax positions taken during the current year
 
17.8

 
6.5

Impact of foreign currency exchange rates
 
(.3
)
 
(5.0
)
Lapse of applicable statutes of limitations
 
(4.4
)
 
(4.5
)
  Increase in unrecognized tax benefits as a result
      of tax positions taken during prior years
 
1.1

 
2.5

Decreases in unrecognized tax benefits as a result
    of tax positions taken during prior years
 
(2.4
)
 
(3.8
)
Settlements with taxing authorities
 
(8.0
)
 
(.3
)
Balance, end of year
 
$
296.7

 
$
143.0


   
Several of our rigs are owned by subsidiaries in Switzerland that are subject to a special finance taxation regime under Swiss income tax rules.  Swiss federal and cantonal governments have enacted tax legislation (“Swiss tax reform”) effective January 1, 2020.  Under Swiss tax reform, the finance taxation regime has been abolished but our Swiss subsidiaries will remain subject to the finance taxation regime through December 31, 2021 and transition to deriving income tax based on net income beginning January 1, 2022.  There are various uncertainties relating to the application of Swiss tax reform to finance taxation regime taxpayers, the most prominent of which is the determination of the Swiss tax basis of property and equipment.  After considering these uncertainties and all information currently available, we have concluded the tax basis of the property and equipment of our Swiss subsidiaries will more likely than not approximate its U.S. GAAP basis and, accordingly, we have not recognized deferred taxes.  As the Swiss tax authorities further clarify the application of Swiss tax reform to finance taxation regime taxpayers, we may recognize deferred tax adjustments and they may have a material effect on our consolidated financial statements.


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Accrued interest and penalties totaled $58.9 million and $40.5 million as of December 31, 2019 and 2018, respectively, and were included in other liabilities on our consolidated balance sheets. We recognized a net expense of $5.7 million, $1.9 million and $4.4 million associated with interest and penalties during the years ended December 31, 2019, 2018, and 2017 respectively. Interest and penalties are included in current income tax expense in our consolidated statements of operations.
 
Three of our subsidiaries file U.S. tax returns and the tax returns of one or more of these subsidiaries is under exam for years 2009 to 2012 and for 2014 and subsequent years. None of these examinations are expected to have an impact on the Company's consolidated results of operations and cash flows. Tax years as early as 2005 remain subject to examination in the other major tax jurisdictions in which we operated.

Statutes of limitations applicable to certain of our tax positions lapsed during 2019, 2018 and 2017, resulting in net income tax benefits, inclusive of interest and penalties, of $5.3 million, $5.3 million and $1.1 million, respectively.
  
Absent the commencement of examinations by tax authorities, statutes of limitations applicable to certain of our tax positions will lapse during 2020.  Therefore, it is reasonably possible that our unrecognized tax benefits will decline during the next 12 months by $800,000, inclusive of $550,000 of accrued interest and penalties, all of which would impact our consolidated effective income tax rate if recognized.
    
Recent Tax Assessments

During 2019, the Luxembourg tax authorities issued aggregate tax assessments totaling approximately €142.0 million (approximately $159.0 million converted using the current period-end exchange rates) related to tax years 2014, 2015 and 2016 for several of Rowan's Luxembourg subsidiaries, which assessments accrue interest at the rate of 7.2% per annum. We may make a payment to the Luxembourg tax authorities in advance of the final resolution of these assessments. Although the outcome of such assessments cannot be predicted with certainty, unfavorable outcomes could have a material adverse effect on our financial position, operating results and cash flows. We have recorded a $104 million liability for these assessments as of December 31, 2019.

During 2019, the Australian tax authorities issued aggregate tax assessments totaling approximately A$101 million (approximately $70.9 million converted at current period-end exchange rates) plus interest related to the examination of certain of our tax returns for the years 2011 through 2016. During the third quarter of 2019, we made a A$42 million payment (approximately $29 million at then-current exchange rates) to the Australian tax authorities to litigate the assessment. We have recorded a $15 million liability for these assessments as of December 31, 2019. We believe our tax returns are materially correct as filed, and we are vigorously contesting these assessments. Although the outcome of such assessments and related administrative proceedings cannot be predicated with certainty, we do not expect these matters to have a material adverse effect on our financial position, operating results and cash flows.

Undistributed Earnings
    
Dividend income received by Valaris plc from its subsidiaries is exempt from U.K. taxation. We do not provide deferred taxes on undistributed earnings of certain subsidiaries because our policy and intention is to reinvest such earnings indefinitely. Each of the subsidiaries for which we maintain such policy has sufficient net assets, liquidity, contract backlog and/or other financial resources available to meet operational and capital investment requirements, which allows us to continue to maintain our policy of reinvesting the undistributed earnings indefinitely.

As of December 31, 2019, the aggregate undistributed earnings of the subsidiaries for which we maintain a policy and intention to reinvest earnings indefinitely totaled $289.0 million. Should we make a distribution from these subsidiaries in the form of dividends or otherwise, we would be subject to additional income taxes. The unrecognized deferred tax liability related to these undistributed earnings was not practicable to estimate as of December 31, 2019.


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13.  COMMITMENTS AND CONTINGENCIES

Capital Commitments

The following table summarizes the estimated timing of our remaining contractual payments of our rigs under construction as of December 31, 2019 for our rigs under construction and (in millions): 
 
 
2020
 
2021
 
2022
 
Thereafter
 
Total(1)
VALARIS DS-13(2)
 
$

 
$
83.9

 
$

 
$

 
$
83.9

VALARIS DS-14(2)
 

 

 
165.0

 

 
165.0

 
 
$


$
83.9


$
165.0

 
$

 
$
248.9



(1) 
Total commitments are based on fixed-price shipyard construction contracts, exclusive of costs associated with project management, commissioning and systems integration testing. Total commitments also exclude holding costs and interest.

Based on our current projections, excluding integration-related capital expenditures, we expect capital expenditures during 2020 to approximate $160 million for newbuild construction, rig enhancement projects and minor upgrades and improvements. Approximately $30 million of our projected capital expenditures is reimbursable by our customers. Depending on market conditions and opportunities, we may reduce our planned expenditures or make additional capital expenditures to upgrade rigs for customer requirements or acquire additional rigs.

(2) 
During the third quarter of 2019, we entered into amendments to our construction agreements with the shipyard for VALARIS DS-13 and VALARIS DS-14 to provide for, among other things, two-year extensions of the delivery date of each rig in exchange for payment of all accrued holding costs through March 31, 2019, totaling approximately $23 million. The new delivery dates for the VALARIS DS-13 and VALARIS DS-14 are September 30, 2021 and June 30, 2022, respectively. We can elect to request earlier delivery in certain circumstances. The interest rate on the final milestone payments increased from 5% to 7% per annum from October 1, 2019, for the VALARIS DS-13, and from July 1, 2020, for the VALARIS DS-14, until the actual delivery dates. The final milestone payments and interest are due at the new delivery dates (or, if accelerated, the actual delivery dates) and are estimated to be approximately $313.3 million in aggregate for both rigs, inclusive of interest, assuming we take delivery on the new delivery dates. In lieu of making the final milestone payments, we have the option to take delivery of the rigs and issue a promissory note for each rig to the shipyard owner for the amount due. If we issue the promissory note to the shipyard owner, we would also be required to provide a guarantee from Valaris plc.

Upon delivery, the remaining milestone payments and accrued interest thereon may be financed through a promissory note with the shipyard for each rig. The promissory notes will bear interest at a rate of 9% per annum with a maturity date of December 30, 2022 and will be secured by a mortgage on each respective rig. The remaining milestone payments for VALARIS DS-13 and VALARIS DS-14 are included in the table above in the period in which we expect to take delivery of the rig. However, we may elect to execute the promissory notes and defer payment until December 2022.

DSA Dispute

On January 4, 2016, Petrobras sent a notice to us declaring the drilling services agreement with Petrobras (the "DSA") for VALARIS DS-5, a drillship ordered from Samsung Heavy Industries, a shipyard in South Korea ("SHI"), void effective immediately, reserving its rights and stating its intention to seek any restitution to which it may be entitled. The previously disclosed arbitral hearing on liability related to the matter was held in March 2018. Prior to the arbitration tribunal issuing its decision, we and Petrobras agreed in August 2018 to a settlement of all claims relating to the DSA. No payments were made by either party in connection with the settlement agreement. The parties agreed

142



to normalize business relations and the settlement agreement provides for our participation in current and future Petrobras tenders on the same basis as all other companies invited to these tenders. No losses were recognized during 2018 with respect to this settlement as all disputed receivables with Petrobras related to the DSA were fully reserved in 2015.

In April 2016, we initiated separate arbitration proceedings in the U.K. against SHI for the losses incurred in connection with the foregoing Petrobras arbitration and certain other losses relating to the DSA. In January 2018, the arbitration tribunal for the SHI matter issued an award on liability fully in our favor. The January 2018 arbitration award provides that SHI is liable to us for $10 million or damages that we can prove. We submitted our claim for damages to the tribunal, and the arbitral hearing on damages owed to us by SHI took place during the first quarter of 2019.

In May 2019, the arbitration tribunal for the SHI matter awarded us $180.0 million in damages. Further, we are entitled to claim interest on this award and costs incurred in connection with this matter. In June 2019, we and SHI filed separate applications with the English High Court to seek leave to appeal the damages awarded.

In December 2019, the English High Court denied the parties’ applications for leave to appeal the tribunal’s $180.0 million damages award. Following this decision, the parties reached an agreement and SHI paid us $200.0 million in cash. Collection of this payment resulted in the recognition of a gain of the same amount, which is included in other, net, in our consolidated statement of operations for the year ended December 31, 2019. This payment, along with the previously disclosed settlement and normalization of our business relationship with Petrobras, concludes our dispute surrounding VALARIS DS-5.

Indonesian Well-Control Event

In July 2019, a well being drilled offshore Indonesia by one of our jackup rigs experienced a well-control event requiring the cessation of drilling activities. The operator could seek to terminate the contract under certain circumstances. If this drilling contract were to be terminated for cause, it would result in an approximate $8.5 million decrease in our backlog as of December 31, 2019.

Indonesian authorities have initiated a preliminary investigation into the event and have contacted the customer, us and other parties involved in drilling the well for additional information. We are cooperating with the Indonesian authorities. We cannot predict the scope or ultimate outcome of this preliminary investigation or whether the Indonesian authorities will open a full investigation into our involvement in this matter. If the Indonesian authorities determine that we violated local laws in connection with this matter, we could be subject to penalties including environmental or other liabilities, which may have a material adverse impact on us.

Middle East Dispute

On July 30, 2019, we received notice that a local partner of legacy Ensco plc in the Middle East filed a lawsuit in the U.K. against the Company alleging it induced the breach of a non-compete provision in an agreement between the local partner and a subsidiary of the Company.  The lawsuit included a claim for an unspecified amount of damages in excess of £100 million and other relief.  The Company expects to reach an agreement to settle this matter and to acquire the local partner's interest in the subsidiary for an aggregate amount of $27.5 million. Of this amount, we concluded that $20.3 million was attributable to the settlement of the dispute and was recognized as a loss included in other, net, in our consolidated statement of operations for the year ended December 31, 2019. The remaining amount is attributable to the acquisition of the local partner's interest in the subsidiary and will be recorded to equity in 2020.

ARO Funding Obligations

Valaris and Saudi Aramco have agreed to take all steps necessary to ensure that ARO purchases at least 20 newbuild jackup rigs ratably over an approximate 10-year period. In January 2020, ARO ordered the first two newbuild jackups for delivery scheduled in 2022. The partners intend for the newbuild jackup rigs to be financed out of available

143



cash from ARO's operations and/or funds available from third-party debt financing. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. The partners agreed that Saudi Aramco, as a customer, will provide drilling contracts to ARO in connection with the acquisition of the newbuild rigs. The initial contracts for each newbuild rig will be determined using a pricing mechanism that targets a six-year payback period for construction costs on an EBITDA basis. The initial eight-year contracts will be followed by a minimum of another eight years of term, re-priced in three-year intervals based on a market pricing mechanism.

  Other Matters

In addition to the foregoing, we are named defendants or parties in certain other lawsuits, claims or proceedings incidental to our business and are involved from time to time as parties to governmental investigations or proceedings, including matters related to taxation, arising in the ordinary course of business. Although the outcome of such lawsuits or other proceedings cannot be predicted with certainty and the amount of any liability that could arise with respect to such lawsuits or other proceedings cannot be predicted accurately, we do not expect these matters to have a material adverse effect on our financial position, operating results and cash flows.

In the ordinary course of business with customers and others, we have entered into letters of credit to guarantee our performance as it relates to our drilling contracts, contract bidding, customs duties, tax appeals and other obligations in various jurisdictions. Letters of credit outstanding as of December 31, 2019 totaled $99.5 million and are issued under facilities provided by various banks and other financial institutions. Obligations under these letters of credit and surety bonds are not normally called, as we typically comply with the underlying performance requirement. As of December 31, 2019, we had not been required to make collateral deposits with respect to these agreements.

14.  LEASES

We have operating leases for office space, facilities, equipment, employee housing and certain rig berthing facilities. For all asset classes, except office space, we account for the lease component and the non-lease component as a single lease component. Our leases have remaining lease terms of less than one year to 10 years, some of which include options to extend. Additionally, we sublease certain office space to third parties.

During the year ended December 31, 2019, we recorded lease impairments of $5.6 million related to the impairment of the right-of-use assets associated with an office space and a leased yard facility that were abandoned due to the consolidation of certain corporate offices and leased facilities.

The components of lease expense as of December 31, 2019 is as follows (in millions):
 
 
Long-term operating lease cost
$
29.5

Short-term operating lease cost
12.2

Sublease income
(2.4
)
Total operating lease cost
$
39.3



Supplemental balance sheet information related to our operating leases is as follows (in millions, except lease term and discount rate) as of December 31, 2019:

144



 
 
Operating lease right-of-use assets(1)
$
58.1

 
 
Current lease liability(1)
$
21.1

Long-term lease liability(1)
51.8

Total operating lease liabilities
$
72.9

 
 
Weighted-average remaining lease term (in years)
5.1

 
 
Weighted-average discount rate (2)
8.23
%

(1) 
The right-of-use assets include $12.2 million acquired in the Rowan Transaction. The current and long-term lease liabilities include $3.9 million and $10.6 million, respectively, assumed in the Rowan Transaction.

(2) 
Represents our estimated incremental borrowing cost on a secured basis for similar terms as the underlying leases.

For the year ended December 31, 2019, cash paid for amounts included in the measurement of our operating lease liabilities was $29.9 million.

We are obligated under leases for certain of our offices and equipment. Rental expense relating to operating leases was $40.1 million and $37.0 million during the years ended December 31, 2018 and 2017, respectively.

Maturities of lease liabilities as of December 31, 2019 were as follows (in millions):
 
 
2020
$
25.4

2021
18.4

2022
12.6

2023
10.7

2024
8.1

Thereafter
17.2

Total lease payments
$
92.4

Less imputed interest
19.5

Total
$
72.9



Future minimum rental payments under non-cancelable operating leases as of December 31, 2018 were as follows (in millions):
 
 
2019
$
32.3

2020
18.7

2021
11.9

2022
9.2

2023
8.9

Thereafter
15.2

Total lease payments
$
96.2




145



15.  SEGMENT INFORMATION

    Prior to the Rowan Transaction, our business consisted of three operating segments: (1) Floaters, which included our drillships and semisubmersible rigs, (2) Jackups, and (3) Other, which consisted of management services on rigs owned by third-parties. Floaters and Jackups were also reportable segments.

As a result of the Rowan Transaction, we concluded that we would maintain the aforementioned segment structure while adding ARO as a reportable segment for the new combined company. We also concluded that the activities associated with our arrangements with ARO, consisting of our Transition Services Agreement, Rig Lease Agreements and Secondment Agreement, do not constitute reportable segments and are therefore included within Other in the following segment disclosures. Substantially all of the expenses incurred associated with our Transition Services Agreement are included in general and administrative under "Reconciling Items" in the table set forth below.

General and administrative expense and depreciation expense incurred by our corporate office are not allocated to our operating segments for purposes of measuring segment operating income (loss) and are included in "Reconciling Items." We measure segment assets as property and equipment. The full operating results included below for ARO (representing only results of ARO from the Transaction Date) are not included within our consolidated results and thus deducted under "Reconciling Items" and replaced with our equity in earnings of ARO. See Note 4 for additional information on ARO and related arrangements.

Segment information for each of the years in the three-year period ended December 31, 2019 is presented below (in millions). 

Year Ended December 31, 2019
 
Floaters
 
Jackups
 
ARO
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,014.4

 
$
834.6

 
$
410.5

 
$
204.2

 
$
(410.5
)
 
$
2,053.2

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
  Contract drilling
  (exclusive of depreciation)
898.6

 
788.9

 
280.2

 
118.5

 
(280.2
)
 
1,806.0

  Loss on impairment
88.2

 
10.2

 

 

 
5.6

 
104.0

  Depreciation
378.6

 
212.4

 
40.3

 

 
(21.6
)
 
609.7

  General and administrative

 

 
27.1

 

 
161.8

 
188.9

Equity in earnings of ARO

 

 

 

 
(12.6
)
 
(12.6
)
Operating income (loss)
$
(351.0
)
 
$
(176.9
)

$
62.9

 
$
85.7

 
$
(288.7
)
 
$
(668.0
)
Property and equipment, net
$
10,073.1

 
$
4,322.7

 
$
650.7

 
$
701.1

 
$
(650.7
)
 
$
15,096.9

Capital expenditures
$
31.4

 
$
184.6

 
$
27.5

 
$

 
$
(16.5
)
 
$
227.0



146



Year Ended December 31, 2018
 
Floaters
 
Jackups
 
ARO
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,013.5

 
$
630.9

 
$

 
$
61.0

 
$

 
$
1,705.4

Operating expenses
 
 
 
 
 
 
 
 
 
 

  Contract drilling
  (exclusive of depreciation)
737.4

 
526.5

 

 
55.5

 

 
1,319.4

  Loss on impairment

 
40.3

 

 

 

 
40.3

  Depreciation
311.8

 
153.3

 

 

 
13.8

 
478.9

  General and administrative

 

 

 

 
102.7

 
102.7

Operating income (loss)
$
(35.7
)
 
$
(89.2
)
 
$

 
$
5.5

 
$
(116.5
)
 
$
(235.9
)
Property and equipment, net
$
9,465.6

 
$
3,114.1

 
$

 
$

 
$
36.5

 
$
12,616.2

Capital expenditures
$
105.5

 
$
317.7

 
$

 
$

 
$
3.5

 
$
426.7


Year Ended December 31, 2017
 
Floaters
 
Jackups
 
ARO
 
Other
 
Reconciling Items
 
Consolidated Total
Revenues
$
1,143.5

 
$
640.3

 
$

 
$
59.2

 
$

 
$
1,843.0

Operating expenses
 
 
 
 
 
 
 
 
 
 

  Contract drilling
  (exclusive of depreciation)
624.2

 
512.1

 

 
53.2

 

 
1,189.5

  Loss on impairment
174.7

 
8.2

 

 

 

 
182.9

  Depreciation
297.4

 
131.5

 

 

 
15.9

 
444.8

  General and administrative

 

 

 

 
157.8

 
157.8

Operating income (loss)
$
47.2

 
$
(11.5
)
 
$

 
$
6.0

 
$
(173.7
)
 
$
(132.0
)
Property and equipment, net
$
9,650.9

 
$
3,177.6

 
$

 
$

 
$
45.2

 
$
12,873.7

Capital expenditures
$
470.3

 
$
62.1

 
$

 
$

 
$
4.3

 
$
536.7


 
Information about Geographic Areas
 
As of December 31, 2019, our Floaters segment consisted of 16 drillships, eight dynamically positioned semisubmersible rigs and two moored semisubmersible rigs deployed in various locations. Of the drillships included in our Floaters segment, two ultra-deepwater drillships are under construction in South Korea.  Our Jackups segment consisted of 41 jackup rigs which were deployed in various locations and our Other segment consisted of nine jackup rigs that are leased to our 50/50 joint venture with Saudi Aramco. Additionally, we had three rigs classified as held-for-sale.
 

147



As of December 31, 2019, the geographic distribution of our and ARO's drilling rigs was as follows:
 
Floaters
 
Jackups
 
Other
 
Total
 
ARO
North & South America
10
 
8
 
 
18
 
Europe & the Mediterranean
7
 
14
 
 
21
 
Middle East & Africa
4
 
12
 
9
 
25
 
7
Asia & Pacific Rim
3
 
7
 
 
10
 
Asia & Pacific Rim (under construction)
2
 
 
 
2
 
Held-for-sale
1
 
2
 
 
3
 
Total
27
 
43

9
 
79

7


We provide management services on two rigs owned by third-parties not included in the table above.

For purposes of our long-lived asset geographic disclosure, we attribute assets to the geographic location of the drilling rig as of the end of the applicable year. For new construction projects, assets are attributed to the location of future operation if known or to the location of construction if the ultimate location of operation is undetermined.

Information by country for those countries that account for more than 10% of our long-lived assets as well as the United Kingdom, our country of domicile, was as follows (in millions):
 
Long-lived Assets
 
2019
 
2018
 
2017
Spain
$
3,012.4

 
$
2,306.6

 
$
2,004.2

United States
2,943.9

 
2,270.0

 
2,764.9

Saudi Arabia
1,257.7

 
668.6

 
93.6

United Kingdom
1,204.0

 
1,185.2

 
609.4

Nigeria
787.3

 
1,368.2

 
583.3

Singapore
22.6

 
23.9

 
2,859.3

Other countries
5,869.0

 
4,793.7

 
3,959.0

Total
$
15,096.9


$
12,616.2


$
12,873.7



16.  SUPPLEMENTAL FINANCIAL INFORMATION

Consolidated Balance Sheet Information

Accounts receivable, net, as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Trade
 
$
466.4

 
$
301.7

Other
 
60.3

 
46.4

 
 
526.7

 
348.1

Allowance for doubtful accounts
 
(6.0
)
 
(3.4
)
 
 
$
520.7

 
$
344.7




148



Other current assets as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Materials and supplies
 
$
340.1

 
$
268.1

Prepaid taxes
 
36.2

 
35.0

Deferred costs
 
23.3

 
23.5

Prepaid expenses
 
13.5

 
15.2

Other
 
33.4

 
19.1

 
 
$
446.5

 
$
360.9


    
Other assets as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Right-of-use assets
 
$
58.1

 
$

Tax receivables
 
36.3

 
8.4

Deferred tax assets
 
26.6

 
29.4

Supplemental executive retirement plan assets
 
26.0

 
27.2

Intangible assets
 
11.9

 
2.5

Deferred costs
 
7.1

 
13.5

Other
 
22.3

 
16.8

 
 
$
188.3

 
$
97.8



Accrued liabilities and other as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Personnel costs
 
$
134.4

 
$
82.5

Accrued interest
 
115.2

 
100.6

Income and other taxes payable
 
61.2

 
36.9

Deferred revenue
 
30.0

 
56.9

Lease liabilities
 
21.1

 

Other
 
55.8

 
41.1

 
 
$
417.7

 
$
318.0



Other liabilities as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Unrecognized tax benefits (inclusive of interest and penalties)
 
$
323.1

 
$
177.0

Pension and other post-retirement benefits
 
246.7

 

Deferred tax liabilities
 
99.0

 
70.7

Intangible liabilities
 
52.1

 
53.5

Lease liabilities
 
51.8

 

Supplemental executive retirement plan liabilities
 
26.7

 
28.1

Personnel costs
 
24.5

 
25.1

Deferred revenue
 
9.7

 
20.5

Other
 
33.8

 
21.1

 
 
$
867.4

 
$
396.0


 

149



Accumulated other comprehensive income as of December 31, 2019 and 2018 consisted of the following (in millions):
 
 
2019
 
2018
Derivative instruments
 
$
22.6

 
$
12.6

Pension and other post-retirement benefits
 
(21.7
)
 

Currency translation adjustment
 
7.1

 
7.3

Other
 
(1.8
)
 
(1.7
)
 
 
$
6.2

 
$
18.2



Consolidated Statement of Operations Information

Repair and maintenance expense related to continuing operations for each of the years in the three-year period ended December 31, 2019 was as follows (in millions):
 
 
2019
 
2018
 
2017
Repair and maintenance expense
 
$
303.7

 
$
198.4

 
$
188.7



Other, net, for each of the years in the three-year period ended December 31, 2019 consisted of the following (in millions):
 
 
2019
 
2018
 
2017
Gain on bargain purchase and measurement period adjustments
 
$
637.0

 
$
1.8

 
$
140.2

SHI settlement
 
200.0

 

 

Gain (loss) on extinguishment of debt
 
194.1

 
(19.0
)
 
(2.6
)
Settlement of legal dispute
 
(20.3
)
 

 

Currency translation adjustments
 
(7.4
)
 
(17.2
)
 
(5.1
)
Other
 
1.0

 
(.4
)
 
1.9

 
 
$
1,004.4

 
$
(34.8
)
 
$
134.4



Consolidated Statement of Cash Flows Information
 
Net cash provided by (used in) operating activities of continuing operations attributable to the net change in operating assets and liabilities for each of the years in the three-year period ended December 31, 2019 was as follows (in millions):
 
 
2019
 
2018
 
2017
(Increase) decrease in accounts receivable
 
$
29.5

 
$
(6.2
)
 
$
83.2

Increase in other assets
 
(32.0
)
 
(2.8
)
 
(14.0
)
Increase (Decrease) in liabilities
 
(25.4
)
 
2.7

 
3.2

 
 
$
(27.9
)
 
$
(6.3
)

$
72.4



During periods in which our business contracts, resulting in significantly lower revenues and expenses as compared to the prior year, we typically generate positive cash flows from the net change in operating assets and liabilities as the impact from the collection of receivables that were accrued during the prior period is generally larger than the impact from the payment of expenses incurred in the prior period. During 2019, we experienced moderate improvements in fleet utilization coupled with the Rowan Transaction that resulted in negative cash flows from changes in operating assets and liabilities. During 2018, our business contracted at a more moderate pace, resulting in modest negative cash flows from the net change in operating assets and liabilities. During 2017, our business contracted significantly as compared to the respective prior year periods resulting in positive cash generated from the net change in operating assets and liabilities.


150



Cash paid for interest and income taxes for each of the years in the three-year period ended December 31, 2019 was as follows (in millions):
 
 
2019
 
2018
 
2017
Interest, net of amounts capitalized
 
$
410.0

 
$
232.6

 
$
199.8

Income taxes
 
107.6

 
58.4

 
62.8



Capitalized interest totaled $20.9 million, $62.6 million and $72.5 million during the years ended December 31, 2019, 2018 and 2017, respectively. Capital expenditure accruals totaling $16.3 million, $27.8 million and $243.3 million for the years ended December 31, 2019, 2018 and 2017, respectively, were excluded from investing activities in our consolidated statements of cash flows. 

Amortization, net, includes amortization of deferred mobilization revenues and costs, deferred capital upgrade revenues, intangible amortization and other amortization.

Other includes amortization of debt discounts and premiums, deferred financing costs, deferred charges for income taxes incurred on intercompany transfers of drilling rigs and other items.

Concentration of Risk

We are exposed to credit risk relating to our receivables from customers, our cash and cash equivalents, investments and our use of derivatives in connection with the management of foreign currency exchange rate risk. We mitigate our credit risk relating to receivables from customers, which consist primarily of major international, government-owned and independent oil and gas companies, by performing ongoing credit evaluations. We also maintain reserves for potential credit losses, which generally have been within our expectations. We mitigate our credit risk relating to cash and investments by focusing on diversification and quality of instruments. Short-term investments consist of a portfolio of time deposits held with several well-capitalized financial institutions, and we monitor the financial condition of those financial institutions.

We mitigate our credit risk relating to counterparties of our derivatives through a variety of techniques, including transacting with multiple, high-quality financial institutions, thereby limiting our exposure to individual counterparties and by entering into ISDA Master Agreements, which include provisions for a legally enforceable master netting agreement, with our derivative counterparties. See "Note 8 - Derivative Instruments" for additional information on our derivative activity.

The terms of the ISDA agreements may also include credit support requirements, cross default provisions, termination events or set-off provisions. Legally enforceable master netting agreements reduce credit risk by providing protection in bankruptcy in certain circumstances and generally permitting the closeout and netting of transactions with the same counterparty upon the occurrence of certain events.

Consolidated revenues by customer for the years ended December 31, 2019, 2018 and 2017 were as follows:
 
 
2019
 
2018
 
2017
Total(1)
 
16
%
 
15
%
 
22
%
BP (2)
 
9
%
 
7
%
 
15
%
Saudi Aramco(3)
 
7
%
 
11
%
 
9
%
Petrobras(4)
 
4
%
 
8
%
 
11
%
Other
 
64
%
 
59
%
 
43
%
 

100
%

100
%
 
100
%



151



(1) 
For the years ended December 31, 2019, 93% of revenues provided by Total were attributable to the Floaters segment and the remainder was attributable to the Jackup segment. During the years 2018 and 2017, all Total revenues were attributable to the Floater segment.

(2) 
For the year ended December 31, 2019, 16%, 43% and 41% of BP revenues were attributable to our Floater, Other and Jackup segments, respectively.
For the year ended December 31, 2018, 27%, 53% and 20% of BP revenues were attributable to our Floater, Other and Jackup segments, respectively.

For the year ended December 31, 2017, 78% of BP revenues were attributable to our Floater segment and the remaining revenues were attributable to our Other segment.

(3) 
For the years ended December 31, 2019, 2018 and 2017, all Saudi Aramco revenues were attributable to the Jackup segment.

(4) 
For the years ended December 31, 2019, 2018 and 2017, all Petrobras revenues were attributable to the Floater segment.

For purposes of our geographic disclosure, we attribute revenues to the geographic location where such revenues are earned. Consolidated revenues by region, including the United Kingdom, our country of domicile, for the years ended December 31, 2019, 2018 and 2017 were as follows (in millions):
 
 
2019
 
2018
 
2017
Saudi Arabia(1)
 
$
313.4

 
$
182.2

 
$
171.8

U.S. Gulf of Mexico(2)
 
301.0

 
214.7

 
149.8

Angola(3)
 
284.0

 
285.7

 
445.7

United Kingdom(4)
 
213.1

 
192.6

 
164.6

Australia(5)
 
204.2

 
283.9

 
206.7

Brazil(6)
 
117.8

 
139.6

 
196.2

Egypt(7)
 
40.4

 
31.2

 
214.8

Other
 
579.3

 
375.5

 
293.4

 
 
$
2,053.2


$
1,705.4


$
1,843.0



(1) 
For the years ended December 31, 2019, 65% and 35% of revenues were attributable to our Jackup and Other segments, respectively. For the years ended December 31, 2018 and 2017, all revenues earned were attributable to our Jackup segment.

(2) 
For the years ended December 31, 2019, 2018 and 2017, 46%, 30% and 29% of revenues earned in the U.S. Gulf of Mexico, respectively, were attributable to our Floaters segment, 28%, 42% and 31% of revenues were attributable to our Jackup segment, respectively, and the remaining revenues were attributable to our Other segment, respectively.

(3) 
For the years ended December 31, 2019, 2018 and 2017, 87%, 86% and 88% of revenues earned in Angola, respectively, were attributable to our Floaters segment with the remaining revenues attributable to our Jackup segment.

(4) 
For the years ended December 31, 2019, 2018 and 2017, all revenues earned in the United Kingdom were attributable to our Jackup segment.


152



(5) 
For the years ended December 31, 2019, 2018 and 2017, 90%, 92% and 87% of revenues earned in Australia, respectively, were attributable to our Floaters segment with the remaining revenues attributable to our Jackup segment.

(6) 
For the years ended December 31, 2019, 2018 and 2017, all revenues earned in Brazil were attributable to our Floaters segment.

(7) 
For the years ended December 31, 2019, 2018 and 2017, all revenues earned in Egypt were attributable to our Floaters segment.




153



17.  GUARANTEE OF REGISTERED SECURITIES

In connection with the Pride acquisition, Valaris and Pride entered into a supplemental indenture to the indenture dated as of July 1, 2004 between Pride and the Bank of New York Mellon, as indenture trustee, providing for, among other matters, the full and unconditional guarantee by Valaris of Pride’s 6.875% senior notes due 2020 and 7.875% senior notes due 2040, which had an aggregate outstanding principal balance of $422.9 million as of December 31, 2019. The Valaris guarantee provides for the unconditional and irrevocable guarantee of the prompt payment, when due, of any amount owed to the holders of the notes.
 
Valaris is also a full and unconditional guarantor of the 7.2% Debentures due 2027 issued by Ensco International Incorporated in November 1997, which had an aggregate outstanding principal balance of $112.1 million as of December 31, 2019.
 
Pride International LLC and Ensco International Incorporated are 100% owned subsidiaries of Valaris. All guarantees are unsecured obligations of Valaris ranking equal in right of payment with all of its existing and future unsecured and unsubordinated indebtedness.

The following tables present our condensed consolidating statements of operations for each of the years in the three-year period ended December 31, 2019; our condensed consolidating statements of comprehensive income (loss) for each of the years in the three-year period ended December 31, 2019; our condensed consolidating balance sheets as of December 31, 2019 and 2018; and our condensed consolidating statements of cash flows for each of the years in the three-year period ended December 31, 2019, in accordance with Rule 3-10 of Regulation S-X. 


154



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Year Ended December 31, 2019
(in millions)
 
Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris  
 
Consolidating Adjustments
 
Total  
OPERATING REVENUES
$
56.7

 
$
165.5

 
$

 
$
2,168.9

 
$
(337.9
)
 
$
2,053.2

OPERATING EXPENSES
 
 
 
 
 
 
 
 
 
 
 
Contract drilling (exclusive of depreciation)
82.6

 
147.1

 

 
1,914.2

 
(337.9
)
 
1,806.0

Loss on impairment

 

 

 
104.0

 

 
104.0

Depreciation
.1

 
17.3

 

 
592.3

 

 
609.7

General and administrative
85.5

 
.4

 

 
103.0

 

 
188.9


168.2

 
164.8

 

 
2,713.5

 
(337.9
)
 
2,708.6

EQUITY IN EARNINGS OF ARO

 

 

 
(12.6
)
 

 
(12.6
)
OPERATING INCOME (LOSS)
(111.5
)
 
0.7

 

 
(557.2
)
 

 
(668.0
)
OTHER INCOME (EXPENSE), NET
723.9

 
(35.7
)
 
(80.8
)
 
(20.2
)
 
17.0

 
604.2

INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
612.4

 
(35.0
)

(80.8
)

(577.4
)

17.0


(63.8
)
INCOME TAX EXPENSE

 
39.8

 

 
88.6

 

 
128.4

EQUITY EARNINGS (LOSSES) IN AFFILIATES, NET OF TAX
(810.4
)
 
47.8

 
25.0

 

 
737.6

 

NET LOSS
(198.0
)
 
(27.0
)

(55.8
)

(666.0
)

754.6


(192.2
)
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
(5.8
)
 

 
(5.8
)
NET LOSS ATTRIBUTABLE TO VALARIS
$
(198.0
)
 
$
(27.0
)

$
(55.8
)

$
(671.8
)

$
754.6


$
(198.0
)


155



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Year Ended December 31, 2018
(in millions)
 
Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris  
 
Consolidating Adjustments
 
Total  
OPERATING REVENUES
$
49.5

 
$
155.2

 
$

 
$
1,802.8

 
$
(302.1
)
 
$
1,705.4

OPERATING EXPENSES
 
 
 
 
 
 
 
 
 
 


Contract drilling (exclusive of depreciation)
51.0

 
139.5

 

 
1,431.0

 
(302.1
)
 
1,319.4

Loss on impairment

 

 

 
40.3

 

 
40.3

Depreciation

 
14.2

 

 
464.7

 

 
478.9

General and administrative
46.3

 
.4

 

 
56.0

 

 
102.7

OPERATING INCOME (LOSS)
(47.8
)

1.1




(189.2
)



(235.9
)
OTHER INCOME (EXPENSE), NET
2.7

 
(135.2
)
 
(89.0
)
 
(109.0
)
 
27.5

 
(303.0
)
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
(45.1
)

(134.1
)

(89.0
)

(298.2
)

27.5


(538.9
)
INCOME TAX EXPENSE

 
43.3

 

 
46.3

 

 
89.6

DISCONTINUED OPERATIONS, NET

 

 

 
(8.1
)
 

 
(8.1
)
EQUITY EARNINGS (LOSSES) IN AFFILIATES, NET OF TAX
(594.6
)
 
121.8

 
93.3

 

 
379.5

 

NET INCOME (LOSS)
(639.7
)

(55.6
)

4.3


(352.6
)

407.0


(636.6
)
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
(3.1
)
 

 
(3.1
)
NET INCOME (LOSS) ATTRIBUTABLE TO VALARIS
$
(639.7
)

$
(55.6
)

$
4.3


$
(355.7
)

$
407.0


$
(639.7
)


156



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Year Ended December 31, 2017
(in millions)
 
Valaris plc
 
ENSCO International Incorporated 
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total  
OPERATING REVENUES
$
52.9

 
$
163.3

 
$

 
$
1,941.2

 
$
(314.4
)
 
$
1,843.0

OPERATING EXPENSES
 

 
 

 
 

 
 

 
 

 
 

Contract drilling (exclusive of depreciation)
50.0

 
149.9

 

 
1,304.0

 
(314.4
)
 
1,189.5

Loss on impairment

 

 

 
182.9

 

 
182.9

Depreciation

 
15.9

 

 
428.9

 

 
444.8

General and administrative
45.4

 
50.8

 

 
61.6

 

 
157.8

OPERATING LOSS
(42.5
)

(53.3
)
 


(36.2
)



(132.0
)
OTHER INCOME (EXPENSE), NET
(6.8
)
 
(110.5
)
 
(71.7
)
 
110.5

 
14.5

 
(64.0
)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
(49.3
)

(163.8
)
 
(71.7
)

74.3


14.5


(196.0
)
INCOME TAX EXPENSE

 
45.0

 

 
64.2

 

 
109.2

DISCONTINUED OPERATIONS, NET

 

 

 
1.0

 

 
1.0

EQUITY EARNINGS (LOSSES) IN AFFILIATES, NET OF TAX
(254.4
)
 
129.6

 
84.2

 

 
40.6

 

NET INCOME (LOSS)
(303.7
)

(79.2
)

12.5


11.1


55.1


(304.2
)
NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
.5

 

 
.5

NET INCOME (LOSS) ATTRIBUTABLE TO VALARIS
$
(303.7
)

$
(79.2
)

$
12.5


$
11.6


$
55.1


$
(303.7
)






157



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
Year Ended December 31, 2019
(in millions)
 
 Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-Guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total
 
 
 
 
 
 
 
 
 
 
 
 
NET LOSS
$
(198.0
)
 
$
(27.0
)
 
$
(55.8
)
 
$
(666.0
)
 
$
754.6

 
$
(192.2
)
OTHER COMPREHENSIVE INCOME (LOSS), NET
 
 
 
 
 
 
 
 
 
 


Net changes in pension and other postretirement plan assets and benefit obligations recognized in other comprehensive loss, net of income tax benefits of ($5.9 million)

 

 

 
(21.7
)
 

 
$
(21.7
)
Net change in fair value of derivatives

 
1.6

 

 

 

 
1.6

Reclassification of net gains on derivative instruments from other comprehensive loss into net loss

 
8.3

 

 

 

 
8.3

Other

 

 

 
(.2
)
 

 
(.2
)
NET OTHER COMPREHENSIVE INCOME (LOSS)

 
9.9

 

 
(21.9
)
 

 
(12.0
)
 
 
 
 
 
 
 
 
 
 
 


COMPREHENSIVE LOSS
(198.0
)
 
(17.1
)
 
(55.8
)
 
(687.9
)
 
754.6

 
(204.2
)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
(5.8
)
 

 
(5.8
)
COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS
$
(198.0
)
 
$
(17.1
)
 
$
(55.8
)
 
$
(693.7
)
 
$
754.6

 
$
(210.0
)



158



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
Year Ended December 31, 2018
(in millions)
 
 
Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-Guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total
 
 
 
 
 
 
 
 
 
 
 
 
NET INCOME (LOSS)
$
(639.7
)
 
$
(55.6
)
 
$
4.3

 
$
(352.6
)
 
$
407.0

 
$
(636.6
)
OTHER COMPREHENSIVE LOSS, NET
 
 
 
 
 
 
 
 
 
 
 
Net change in fair value of derivatives

 
(9.7
)
 

 

 

 
(9.7
)
Reclassification of net losses on derivative instruments from other comprehensive income into net income

 
(1.0
)
 

 

 

 
(1.0
)
Other

 

 

 
(.5
)
 

 
(.5
)
NET OTHER COMPREHENSIVE LOSS

 
(10.7
)
 

 
(.5
)
 

 
(11.2
)
 
 
 
 
 
 
 
 
 
 
 


COMPREHENSIVE INCOME (LOSS)
(639.7
)
 
(66.3
)
 
4.3

 
(353.1
)
 
407.0

 
(647.8
)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
(3.1
)
 

 
(3.1
)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO VALARIS
$
(639.7
)
 
$
(66.3
)
 
$
4.3

 
$
(356.2
)
 
$
407.0

 
$
(650.9
)




159



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
Year Ended December 31, 2017
(in millions)
 
 
Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-Guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total
 
 
 
 
 
 
 
 
 
 
 
 
NET INCOME (LOSS)
$
(303.7
)
 
$
(79.2
)
 
$
12.5

 
$
11.1

 
$
55.1

 
$
(304.2
)
OTHER COMPREHENSIVE INCOME, NET
 
 
 
 
 
 
 
 
 
 
 
Net change in fair value of derivatives

 
8.5

 

 

 

 
8.5

Reclassification of net gains on derivative instruments from other comprehensive income into net loss

 
.4

 

 

 

 
.4

Other

 

 

 
.7

 

 
.7

NET OTHER COMPREHENSIVE INCOME

 
8.9

 

 
.7

 

 
9.6

 
 
 
 
 
 
 
 
 
 
 


COMPREHENSIVE INCOME (LOSS)
(303.7
)
 
(70.3
)
 
12.5

 
11.8

 
55.1

 
(294.6
)
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 
.5

 

 
.5

COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO VALARIS
$
(303.7
)
 
$
(70.3
)
 
$
12.5

 
$
12.3

 
$
55.1

 
$
(294.1
)





160



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2019
(in millions)
 
Valaris plc
 
ENSCO
International Incorporated
 
Pride International LLC
 
Other
Non-guarantor
Subsidiaries of Valaris
 
Consolidating
Adjustments
 
Total
ASSETS
 
 
 
 
 
 
 
 
 
 
 
CURRENT ASSETS
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$
21.5

 
$

 
$

 
$
75.7

 
$

 
$
97.2

Short-term investments

 


 


 

 


 

Accounts receivable, net 
0.2

 
19.7

 


 
500.8

 

 
520.7

Accounts receivable from
  affiliates
4,031.4

 
386.0

 


 
897.2

 
(5,314.6
)
 

Other
.6

 
11.6

 


 
434.3

 


 
446.5

 Total current assets
4,053.7

 
417.3

 

 
1,908.0

 
(5,314.6
)
 
1,064.4

PROPERTY AND EQUIPMENT, AT COST
1.9

 
108.8

 


 
18,283.1

 


 
18,393.8

Less accumulated depreciation
1.9

 
84.7

 


 
3,210.3

 


 
3,296.9

Property and equipment, net  

 
24.1

 

 
15,072.8

 

 
15,096.9

SHAREHOLDER NOTE FROM
   ARO

 

 

 
452.9

 

 
452.9

INVESTMENT IN ARO

 

 

 
128.7

 

 
128.7

DUE FROM AFFILIATES
73.8

 

 
38.9

 
1,775.7

 
(1,888.4
)
 

INVESTMENTS IN AFFILIATES
9,778.5

 
788.8

 
1,224.9

 

 
(11,792.2
)
 

OTHER ASSETS
7.9

 
3.8

 

 
182.6

 
(6.0
)
 
188.3

 
$
13,913.9

 
$
1,234.0


$
1,263.8


$
19,520.7


$
(19,001.2
)
 
$
16,931.2

LIABILITIES AND SHAREHOLDERS' EQUITY 
 
 
 
 
 
 
 
 
CURRENT LIABILITIES
 
 
 
 
 
 
 
 
 
 
 
 Accounts payable and accrued
  liabilities
$
99.2

 
$
29.3

 
$
12.2

 
$
565.2

 
$

 
$
705.9

Accounts payable to affiliates
818.8

 
147.8

 
815.1

 
3,532.9

 
(5,314.6
)
 

Current maturities of long - term debt

 

 
124.8

 

 

 
124.8

Total current liabilities
918.0

 
177.1

 
952.1

 
4,098.1

 
(5,314.6
)
 
830.7

DUE TO AFFILIATES 
710.3

 
478.8

 
586.6

 
112.7

 
(1,888.4
)
 

LONG-TERM DEBT 
2,990.6

 
111.7

 
373.3

 
2,447.9

 

 
5,923.5

OTHER LIABILITIES
(14.6
)
 
90.6

 

 
797.4

 
(6.0
)
 
867.4

VALARIS
 SHAREHOLDERS' EQUITY (DEFICIT)
9,309.6

 
375.8

 
(648.2
)
 
12,065.9

 
(11,792.2
)
 
9,310.9

NONCONTROLLING INTERESTS

 

 

 
(1.3
)
 

 
(1.3
)
Total equity (deficit)
9,309.6

 
375.8

 
(648.2
)
 
12,064.6

 
(11,792.2
)
 
9,309.6

      
$
13,913.9

 
$
1,234.0


$
1,263.8


$
19,520.7


$
(19,001.2
)
 
$
16,931.2


161



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2018
(in millions)
 
Valaris plc
 
ENSCO
International Incorporated
 
Pride International LLC
 
Other
Non-guarantor
Subsidiaries of Valaris
 
Consolidating
Adjustments
 
Total
ASSETS
 
 
 
 
 
 
 
 
 
 
 
CURRENT ASSETS
 
 
 
 
 
 
 
 
 
 
 
   Cash and cash equivalents
$
199.8

 
$

 
$
2.7

 
$
72.6

 
$

 
$
275.1

Short-term investments
329.0

 

 

 

 

 
329.0

Accounts receivable, net 
7.3

 
25.4

 

 
312.0

 

 
344.7

Accounts receivable from
  affiliates
1,861.2

 
171.4

 

 
131.7

 
(2,164.3
)
 

Other
.6

 
6.0

 

 
354.3

 

 
360.9

 Total current assets
2,397.9

 
202.8

 
2.7

 
870.6

 
(2,164.3
)
 
1,309.7

PROPERTY AND EQUIPMENT, AT COST
1.8

 
125.2

 

 
15,390.0

 

 
15,517.0

Less accumulated depreciation
1.8

 
91.3

 

 
2,807.7

 

 
2,900.8

Property and equipment, net  

 
33.9

 

 
12,582.3

 

 
12,616.2

DUE FROM AFFILIATES
2,413.8

 
234.5

 
125.0

 
2,715.1

 
(5,488.4
)
 

INVESTMENTS IN AFFILIATES
8,522.6

 
3,713.7

 
1,199.9

 

 
(13,436.2
)
 

OTHER ASSETS
8.1

 

 

 
89.7

 

 
97.8

 
$
13,342.4

 
$
4,184.9


$
1,327.6


$
16,257.7


$
(21,088.9
)
 
$
14,023.7

LIABILITIES AND SHAREHOLDERS' EQUITY 
 
 
 
 
 
 
 
 
CURRENT LIABILITIES
 
 
 
 
 
 
 
 
 
 
 
   Accounts payable and accrued
     liabilities
$
85.3

 
$
32.0

 
$
12.7

 
$
398.5

 
$

 
$
528.5

Accounts payable to affiliates
59.7

 
139.5

 
38.2

 
1,926.9

 
(2,164.3
)
 

Total current liabilities
145.0

 
171.5

 
50.9

 
2,325.4

 
(2,164.3
)
 
528.5

DUE TO AFFILIATES 
1,432.0

 
1,226.9

 
1,366.5

 
1,463.0

 
(5,488.4
)
 

LONG-TERM DEBT 
3,676.5

 
149.3

 
502.6

 
682.0

 

 
5,010.4

OTHER LIABILITIES
0.1

 
64.3

 

 
331.6

 

 
396.0

VALARIS
 SHAREHOLDERS' EQUITY (DEFICIT)
8,088.8

 
2,572.9

 
(592.4
)
 
11,458.3

 
(13,436.2
)
 
8,091.4

NONCONTROLLING INTERESTS

 

 

 
(2.6
)
 

 
(2.6
)
Total equity (deficit)
8,088.8

 
2,572.9

 
(592.4
)
 
11,455.7

 
(13,436.2
)
 
8,088.8

      
$
13,342.4

 
$
4,184.9


$
1,327.6


$
16,257.7


$
(21,088.9
)
 
$
14,023.7






162



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
Year Ended December 31, 2019
(in millions)
 
Valaris plc
 
ENSCO International Incorporated  
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total
OPERATING ACTIVITIES
 

 
 

 
 

 
 

 
 

 
 

Net cash provided by (used in) operating activities of continuing operations
$
(181.2
)
 
$
(57.9
)
 
$
(111.3
)
 
$
73.5

 
$

 
$
(276.9
)
INVESTING ACTIVITIES
 
 
 
 
 
 
 
 
 
 
 
Acquisition of Rowan, net of cash acquired

 

 

 
931.9

 

 
931.9

Maturities of short-term investments
474.0

 

 

 

 

 
474.0

Purchases of short-term investments
(145.0
)
 

 

 

 

 
(145.0
)
Additions to property and equipment 

 

 

 
(227.0
)
 

 
(227.0
)
Net proceeds from disposition of assets


 

 

 
17.7

 

 
17.7

Other
(.1
)
 

 

 
.1

 

 

Net cash provided by investing activities of continuing operations
328.9






722.7



 
1,051.6

FINANCING ACTIVITIES
 
 
 
 
 
 
 

 
 

 


Reduction of long-term
  borrowings
(536.6
)
 
(30.4
)
 

 
(361.1
)
 

 
(928.1
)
Borrowings on credit facility
215.0

 

 

 

 

 
215.0

Repayments of credit facility borrowings
(215.0
)
 

 

 

 

 
(215.0
)
Advances from (to) affiliates
220.6

 
88.3

 
108.6

 
(417.5
)
 

 

Debt solicitation fees

 

 

 
(9.5
)
 

 
(9.5
)
Cash dividends paid
(4.5
)
 

 

 

 

 
(4.5
)
Other
(5.5
)
 

 

 
(4.7
)
 

 
(10.2
)
Net cash provided by (used in) financing activities
(326.0
)
 
57.9

 
108.6

 
(792.8
)
 

 
(952.3
)
Effect of exchange rate changes on cash and cash equivalents

 

 

 
(.3
)
 

 
(.3
)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(178.3
)
 


(2.7
)

3.1




(177.9
)
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR
199.8

 

 
2.7

 
72.6

 

 
275.1

CASH AND CASH EQUIVALENTS, END OF YEAR
$
21.5

 
$


$


$
75.7


$


$
97.2


163



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
Year Ended December 31, 2018
(in millions)
 
Valaris plc
 
ENSCO International Incorporated 
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris
 
Consolidating Adjustments
 
Total
OPERATING ACTIVITIES
 

 
 

 
 

 
 

 
 

 
 

Net cash provided by (used in) operating activities of continuing operations
$
18.1

 
$
(135.1
)
 
$
(97.6
)
 
$
158.9

 
$

 
$
(55.7
)
INVESTING ACTIVITIES
 
 
 
 
 
 
 
 
 
 


Maturities of short-term investments
1,030.0

 

 

 

 

 
1,030.0

Purchases of short-term
    investments
(919.0
)
 

 

 

 

 
(919.0
)
Additions to property and
  equipment 

 

 

 
(426.7
)
 

 
(426.7
)
Net proceeds from disposition of assets

 

 

 
11.0

 

 
11.0

Purchase of affiliate debt
(551.7
)
 

 

 

 
551.7

 

Sale of affiliate debt
479.0

 

 

 

 
(479.0
)
 

Net cash provided by (used in) investing activities of continuing operations
38.3

 




(415.7
)

72.7

 
(304.7
)
FINANCING ACTIVITIES
 
 
 
 
 
 
 
 
 
 


Proceeds from issuance of senior notes
1,000.0

 

 

 

 

 
1,000.0

Advances from (to) affiliates
(845.0
)
 
135.1

 
612.5

 
97.4

 

 

Reduction of long-term
  borrowings
(159.9
)
 

 
(537.8
)
 
(0.8
)
 
(72.7
)
 
(771.2
)
Debt issuance costs
(17.0
)
 

 

 

 

 
(17.0
)
Cash dividends paid
(17.9
)
 

 

 

 

 
(17.9
)
Other
(2.0
)
 

 

 
(3.7
)
 

 
(5.7
)
Net cash provided by (used in) financing activities
(41.8
)

135.1


74.7


92.9


(72.7
)
 
188.2

Net cash provided by discontinued operations

 

 

 
2.5

 


2.5

Effect of exchange rate changes on cash and cash equivalents

 

 

 
(.6
)
 

 
(.6
)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
14.6

 


(22.9
)

(162.0
)



(170.3
)
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR
185.2

 

 
25.6

 
234.6

 

 
445.4

CASH AND CASH EQUIVALENTS, END OF YEAR
$
199.8

 
$


$
2.7


$
72.6


$

 
$
275.1


164



VALARIS PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
Year Ended December 31, 2017
(in millions)
 
Valaris plc
 
ENSCO International Incorporated
 
Pride International LLC
 
Other Non-guarantor Subsidiaries of Valaris    
 
Consolidating Adjustments
 
Total
OPERATING ACTIVITIES
 

 
 

 
 
 
 

 
 

 
 

Net cash provided by (used in) operating activities of continuing operations
$
(18.2
)
 
$
(117.6
)
 
$
(100.1
)
 
$
495.3

 
$

 
$
259.4

INVESTING ACTIVITIES
 

 
 

 
 

 
 

 
 

 


Purchases of short-term investments
(1,022.9
)
 

 

 
(17.1
)
 

 
(1,040.0
)
Additions to property and equipment 

 

 

 
(536.7
)
 

 
(536.7
)
Maturities of short-term investments
1,748.0

 
5.5

 

 
289.0

 

 
2,042.5

Net proceeds from disposition of assets

 

 

 
2.8

 

 
2.8

Purchase of affiliate debt
(316.3
)
 

 

 

 
316.3

 

Acquisition of Atwood, net of cash acquired

 

 

 
(871.6
)
 

 
(871.6
)
Net cash provided by (used in) investing activities of continuing operations
408.8


5.5




(1,133.6
)

316.3

 
(403.0
)
FINANCING ACTIVITIES
 

 
 

 
 

 
 

 
 

 


Reduction of long-term borrowing
(220.7
)
 

 

 

 
(316.3
)
 
(537.0
)
Cash dividends paid 
(13.8
)
 

 

 

 

 
(13.8
)
Debt issuance costs
(12.0
)
 

 

 

 

 
(12.0
)
Advances from (to) affiliates
(848.9
)
 
112.1

 
105.9

 
630.9

 

 

Other
(2.6
)
 

 

 
(5.1
)
 

 
(7.7
)
Net cash provided by (used in) financing activities
(1,098.0
)
 
112.1


105.9


625.8


(316.3
)
 
(570.5
)
Net cash used in discontinued operations

 

 

 
(.8
)
 

 
(.8
)
Effect of exchange rate changes on cash and cash equivalents

 

 

 
.6

 

 
.6

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(707.4
)
 


5.8


(12.7
)


 
(714.3
)
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR
892.6

 

 
19.8

 
247.3

 

 
1,159.7

CASH AND CASH EQUIVALENTS, END
       OF YEAR
$
185.2

 
$


$
25.6


$
234.6


$

 
$
445.4



165



18.  UNAUDITED QUARTERLY FINANCIAL DATA

The following tables summarize our unaudited quarterly condensed consolidated income statement data for the years ended December 31, 2019 and 2018 (in millions, except per share amounts):

 
 
2019
 
 
First 
Quarter  
 
Second
Quarter
 
Third
Quarter
 
Fourth 
Quarter
 
Year
Operating revenues
 
$
405.9

 
$
583.9

 
$
551.3

 
$
512.1

 
$
2,053.2

Operating expenses
 
 
 
 

 
 

 
 

 
 

Contract drilling (exclusive of depreciation)
 
332.6

 
500.3

 
496.5

 
476.6

 
1,806.0

Loss on impairment(1)
 

 
2.5

 
88.2

 
13.3

 
104.0

Depreciation
 
125.0

 
157.9

 
163.0

 
163.8

 
609.7

General and administrative
 
29.6

 
81.2

 
36.1

 
42.0

 
188.9

Equity in earnings of ARO
 

 
0.6

 
(3.7
)
 
(9.5
)
 
(12.6
)
Operating loss
 
(81.3
)
 
(157.4
)
 
(236.2
)
 
(193.1
)
 
(668.0
)
Other income (expense), net
 
(75.2
)
 
597.3

 
40.2

 
41.9

 
604.2

Income (loss) from continuing operations before income taxes
 
(156.5
)
 
439.9

 
(196.0
)
 
(151.2
)
 
(63.8
)
Income tax expense
 
31.5

 
32.6

 
1.5

 
62.8

 
128.4

Net income (loss)
 
(188.0
)

407.3


(197.5
)

(214.0
)

(192.2
)
Net (income) loss attributable to noncontrolling interests
 
(2.4
)
 
(1.8
)
 
.4

 
(2.0
)
 
(5.8
)
Net income (loss) attributable to Valaris
 
$
(190.4
)
 
$
405.5


$
(197.1
)

$
(216.0
)
 
$
(198.0
)
Income (loss) per share – basic and diluted
 
 

 
 

 
 

 
 

 


Continuing operations
 
$
(1.75
)
 
$
2.09

 
$
(1.00
)
 
$
(1.09
)
 
$
(1.14
)
Discontinued operations
 

 

 

 

 

 
 
$
(1.75
)
 
$
2.09


$
(1.00
)

$
(1.09
)

$
(1.14
)


(1) 
The quarterly periods included losses associated with the impairment of older, less capable, non-core rigs and operating lease impairments. See "Note 6 - Property and Equipment" and "Note 14 - Leases" for additional information.






166




 
 
2018
 
 
First 
Quarter
 
Second
Quarter
 
Third
Quarter
 
Fourth 
Quarter
 
Year
Operating revenues
 
$
417.0

 
$
458.5

 
$
430.9

 
$
399.0

 
$
1,705.4

Operating expenses
 
 

 
 

 
 

 
 
 
 

Contract drilling (exclusive of depreciation)
 
325.2

 
344.3

 
327.1

 
322.8

 
1,319.4

Loss on impairment(1)
 

 

 

 
40.3

 
40.3

Depreciation
 
115.2

 
120.7

 
120.6

 
122.4

 
478.9

General and administrative
 
27.9

 
26.1

 
25.1

 
23.6

 
102.7

Operating loss
 
(51.3
)
 
(32.6
)
 
(41.9
)
 
(110.1
)
 
(235.9
)
Other expense, net
 
(70.7
)
 
(84.8
)
 
(77.7
)
 
(69.8
)
 
(303.0
)
Loss from continuing operations before income taxes
 
(122.0
)
 
(117.4
)
 
(119.6
)
 
(179.9
)
 
(538.9
)
Income tax expense
 
18.4

 
24.7

 
23.3

 
23.2

 
89.6

Loss from continuing operations
 
(140.4
)
 
(142.1
)
 
(142.9
)
 
(203.1
)
 
(628.5
)
Loss from discontinued operations, net
 
(.1
)
 
(8.0
)
 

 

 
(8.1
)
Net loss
 
(140.5
)
 
(150.1
)
 
(142.9
)
 
(203.1
)
 
(636.6
)
Net (income) loss attributable to noncontrolling interests
 
.4

 
(.9
)
 
(2.1
)
 
(.5
)
 
(3.1
)
Net loss attributable to Valaris
 
$
(140.1
)
 
$
(151.0
)

$
(145.0
)

$
(203.6
)
 
$
(639.7
)
Loss per share – basic and diluted
 
 

 
 

 
 

 
 

 


Continuing operations
 
$
(1.29
)
 
$
(1.31
)
 
$
(1.34
)
 
$
(1.88
)
 
$
(5.82
)
Discontinued operations
 

 
(0.08
)
 

 

 
(0.08
)
 
 
$
(1.29
)
 
$
(1.39
)

$
(1.34
)

$
(1.88
)

$
(5.90
)


(1) 
Fourth quarter included an aggregate loss of $40.3 million associated with the impairment of an older, non-core jackup rig. See "Note 6 - Property and Equipment" for additional information.


167



Item 9.  Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

    Not applicable.
 

Item 9A.  Controls and Procedures

CONCLUSION REGARDING THE EFFECTIVENESS OF DISCLOSURE CONTROLS AND PROCEDURES

Based on their evaluation as of the end of the period covered by this Annual Report on Form 10-K, our management, with the participation of our Chief Executive Officer and Chief Financial Officer, has concluded that our disclosure controls and procedures, as defined in Rule 13a-15 under the Exchange Act, are effective.
 
During the year ended December 31, 2019, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
    
In 2019, we completed our merger with Rowan (See Note 3 to our consolidated financial statements for more information). We are currently integrating Rowan into our operations and internal control processes and, pursuant to the SEC's guidance that a recently acquired business may be excluded from the scope of an assessment of internal control over financial reporting in the year of acquisition, the scope of our assessment of the effectiveness of our internal controls over financial reporting at December 31, 2019 excludes Rowan to the extent not integrated into our control environment.

See "Item 8. Financial Statements and Supplementary Data" for Management's Report on Internal Control Over Financial Reporting.


Item 9B.  Other Information

    Not applicable.


168




PART III


Item 10.  Directors, Executive Officers and Corporate Governance

The information required by this item with respect to our directors, corporate governance matters, committees of the Board of Directors and Section 16(a) of the Exchange Act is contained in our Proxy Statement for the Annual General Meeting of Shareholders ("Proxy Statement") to be filed with the SEC not later than 120 days after the end of our fiscal year ended December 31, 2019 and incorporated herein by reference.

The information required by this item with respect to our executive officers is set forth in "Executive Officers" in Part I of this Annual Report on Form 10-K.

The guidelines and procedures of the Board of Directors are outlined in our Corporate Governance Policy. The committees of the Board of Directors operate under written charters adopted by the Board of Directors. The Corporate Governance Policy and committee charters are available on our website at www.valarisplc.com in the Governance Documents section and are available in print without charge by contacting our Investor Relations Department at 713-430-4607.

We have a Code of Conduct that applies to all employees, including our principal executive officer, principal financial officer and principal accounting officer. The Code of Conduct is available on our website at www.valarisplc.com in the Governance Documents section and is available in print without charge by contacting our Investor Relations Department. We intend to disclose any amendments to or waivers from our Code of Conduct by posting such information on our website. Our Proxy Statement contains governance disclosures, including information on our Code of Conduct, our Corporate Governance Policy, the director nomination process, shareholder director nominations, shareholder communications to the Board of Directors and director attendance at the Annual General Meeting of Shareholders.


Item 11.  Executive Compensation

    The information required by this item is contained in our Proxy Statement and incorporated herein by reference.


169




Item 12.  Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters

Equity Compensation Plan Information
    
The following table summarizes certain information related to our compensation plans under which our shares are authorized for issuance as of December 31, 2019:
Plan category
 
Number of securities
to be issued upon
exercise of
outstanding options,
warrants and rights
 
Weighted-average
exercise price of
outstanding options,
warrants and rights
 
Number of securities
remaining available for
future issuance under
equity compensation
plans (excluding
securities reflected
in column (a))(1)
 
 
(a)
 
(b)(1)
 
(c)
Equity compensation
     plans approved by
      security holders
 

 
$

 
2,471,736

Equity compensation
     plans not approved by
     security holders(2)
 
906,624

 
51.56

 
2,425,751

Total
 
906,624

 
$
51.56

 
4,897,487



170



(1)
Restricted share units and restricted shares do not have an exercise price and, thus, are not reflected in this column.
(2)
Under the 2018 LTIP, 2.3 million shares remained available for future issuances of non-vested share awards, share option awards and performance awards as of December 31, 2019.
 
In connection with the Pride acquisition, we assumed Pride's option plan and the outstanding options thereunder. As of December 31, 2019, options to purchase 7,500 shares at a weighted-average exercise price of $165.51 per share were outstanding under this plan. No shares are available for future issuance under this plan, no further options will be granted under this plan and the plan will be terminated upon the earlier of the exercise or expiration date of the last outstanding option.

In connection with the Atwood acquisition, we assumed Atwood’s Amended and Restated 2007 Long-Term Incentive Plan (the “Atwood LTIP”) and the options outstanding thereunder.  As of December 31, 2019, options to purchase 124,176 shares at a weighted-average exercise price of $99.39 per share were outstanding under this plan.  There were also 96,626 shares remaining available for future issuance, which we may grant to employees and other service providers who were not employed or engaged with us prior to the Atwood acquisition.

The Atwood LTIP, which we adopted in connection with the Atwood acquisition, provides for discretionary equity compensation awards.  Awards may be granted in the form of share options, restricted share awards, share appreciation rights and performance share or unit awards.  All future awards granted under the Atwood LTIP will be subject to such terms and conditions, including vesting terms, as may be determined by the plan administrator at the time of grant.  Following the Atwood acquisition, the Atwood LTIP is administered by and all award decisions will be made on a discretionary basis by our Compensation Committee or Board of Directors.

In connection with the Rowan Transaction, we assumed the Amended and Restated 2013 Rowan Companies plc Incentive Plan (the “Rowan LTIP”) and the non-vested share awards, options, and share appreciation rights outstanding thereunder.  As of December 31, 2019, options to purchase 244,025 shares at a weighted-average exercise price of $25.58 per share, 530,923 share appreciation rights at a weighted-average exercise price of $50.70 per share and 2,075,426 restricted share units were outstanding under this plan.  There were also 2.3 million shares remaining available for future issuance, which we may grant to employees and other service providers who were not employed or engaged with us prior to the Rowan Transaction.

The Rowan LTIP, which we adopted in connection with the Rowan Transaction, provides for discretionary equity compensation awards.  Awards may be granted in the form of share options, restricted share or unit awards, share appreciation rights and performance share or unit awards.  All future awards granted under the Rowan LTIP will be subject to such terms and conditions, including vesting terms, as may be determined by the plan administrator at the time of grant.  Following the Rowan Transaction, the Rowan LTIP is administered by and all award decisions will be made on a discretionary basis by our Compensation Committee or Board of Directors.

Additional information required by this item is included in our Proxy Statement and incorporated herein by reference.


Item 13.  Certain Relationships and Related Transactions, and Director Independence

    The information required by this item is contained in our Proxy Statement and incorporated herein by reference.


Item 14.  Principal Accounting Fees and Services

    The information required by this item is contained in our Proxy Statement and incorporated herein by reference.

PART IV



171



Item 15.  Exhibits, Financial Statement Schedules

(a)
The following documents are filed as part of this report:
 
 
1.  Financial Statements
 
 
Reports of Independent Registered Public Accounting Firm 
88
 
Consolidated Statements of Operations
93
 
Consolidated Statements of Comprehensive Income
94
 
Consolidated Balance Sheets
95
 
Consolidated Statements of Cash Flows
96
 
Notes to Consolidated Financial Statements
97
 
2.  Financial Statement Schedules:
 
 
The schedules for which provision is made in the applicable accounting regulations of the SEC are not required under the related instructions or are inapplicable or provided elsewhere in the financial statements and, therefore, have been omitted.
 
 
 3.  Exhibits
        Exhibit
        Number
 
 
Exhibit
 
 
 
2.1
 
 
 
 
2.2
 
 
 
 
2.3
 
 
 
 
3.1
 
 
 
 
3.2
 
 
 
 
3.3
 
 
 
 
4.1
 
 
 
 
4.2
 
 
 
 

172



4.3
 
 
 
 
4.4
 
 
 
 
4.5
 
 
 
 
4.6
 
 
 
 
4.7
 
 
 
 
4.8
 
 
 
 
4.9
 
 
 
 
4.10
 
 
 
 
4.11
 
 
 
 
4.12
 
 
 
 
4.13
 
 
 
 
4.14
 
 
 
 
4.15
 
 
 
 
4.16
 
 
 
 
4.17
 
 
 
 
4.18
 
 
 
 
4.19
 
 
 
 

173



4.20
 
 
 
 
4.21
 
 
 
 
4.22
 
 
 
 
4.23
 
 
 
 
4.24
 
 
 
 
4.25
 
 
 
 
4.26
 
 
 
 
4.27
 
 
 
 
4.28
 
 
 
 
4.29
 
 
 
 
4.30
 
 
 
 
4.31
 
 
 
 
4.32
 
 
 
 
4.33
 
 
 
 
4.34
 
 
 
 
4.35
 
 
 
 
4.36
 
 
 
 
4.37
 
 
 
 
4.38
 
 
 
 
4.39
 
 
 
 

174



4.40
 
 
 
 
4.41
 
 
 
 
*4.42
 
 
 
 
*4.43
 
 
 
 
*4.44
 
 
 
 
*4.45
 
 
 
 
*4.46
 
 
 
 
*4.47
 
 
 
 
*4.48
 
 
 
 
10.1
 
 
 
 
10.2
 
 
 
 
10.3
 
 
 
 
10.4
 
 
 
 
10.5
 
 
 
 
10.6
 
 
 
 
10.7
 
 
 
 
+10.8
 
 
 
 
+10.9
 
 
 
 

175



+10.10
 
 
 
 
+10.11
 
 
 
 
+10.12
 
 
 
 
+10.13
 
 
 
 
+10.14
 
 
 
 
+10.15
 
 
 
 
+10.16
 
 
 
 
+10.17
 
 
 
 
+10.18
 
 
 
 
+10.19
 
 
 
 
+10.20
 
 
 
 
+10.21
 
 
 
 
+10.22
 
 
 
 
+10.23
 
 
 
 
+10.24
 
 
 
 
+10.25
 
 
 
 

176



+10.26
 
 
 
 
+10.27
 
 
 
 
+*10.28
 
 
 
 
+10.29
 
 
 
 
+10.30
 
 
 
 
+10.31
 
 
 
 
+10.32
 
 
 
 
+10.33
 
 
 
 
+10.34
 
 
 
 
+10.35
 
 
 
 
+10.36
 
 
 
 
+10.37
 
 
 
 
+10.38
 
 
 
 
+10.39
 
 
 
 
+10.40
 
 
 
 
+10.41
 
 
 
 
+10.42
 
 
 
 
+10.43
 
 
 
 

177



+10.44
 
 
 
 
+10.45

 
 
 
 
+10.46
 
 
 
 
+10.47
 
 
 
 
+10.48
 
 
 
 
+10.49
 
 
 
 
+10.50
 
 
 
 
+10.51
 
 
 
 
+10.52
 
 
 
 
+10.53
 
 
 
 
+10.54
 
 
 
 
+10.55
 
 
 
 
+10.56
 
 
 
 
10.57
 
 
 
 
10.58
 
 
 
 
+*10.59
 
 
 
 
+*10.60
 
 
 
 
+*10.61
 
 
 
 

178



+10.62
 
 
 
 
+10.63
 
 
 
 
+10.64
 
 
 
 
+10.65
 
 
 
 
+10.66
 
 
 
 
+10.67
 
 
 
 
+10.68
 
 
 
 
+10.69
 
 
 
 
+10.70
 
 
 
 
+10.71
 
 
 
 
+10.72
 
 
 
 
+10.73
 
 
 
 
+10.74
 
 
 
 
+10.75
 
 
 
 
+10.76
 
 
 
 
+*10.77
 
 
 
 
+10.78
 
 
 
 
+10.79
 
 
 
 
*21.1
 
 
 
 
*23.1
 
 
 
 

179



*31.1
 
 
 
 
*31.2
 
 
 
 
**32.1
 
 
 
 
**32.2
 
 
 
 
*101.INS
 
XBRL Instance Document
 
 
 
*101.SCH
 
XBRL Taxonomy Extension Schema
 
 
 
*101.CAL
 
XBRL Taxonomy Extension Calculation Linkbase
 
 
 
*101.DEF
 
XBRL Taxonomy Extension Definition Linkbase
 
 
 
*101.LAB
 
XBRL Taxonomy Extension Label Linkbase
 
 
 
*101.PRE
 
XBRL Taxonomy Extension Presentation Linkbase
 
 
 
*
**
+     
 
Filed herewith.
Furnished herewith.
Management contracts or compensatory plans and arrangements required to be filed as exhibits pursuant to Item 15(b) of this report.

Certain agreements relating to our long-term debt have not been filed as exhibits as permitted by paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K since the total amount of securities authorized under any such agreements do not exceed 10% of our total assets on a consolidated basis. Upon request, we will furnish to the SEC all constituent agreements defining the rights of holders of our long-term debt not filed herewith.

Item 16.  Form 10-K Summary

    None.

180



SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized, on February 21, 2020.
                       Valaris plc
                       (Registrant)
 
By   /s/         THOMAS P. BURKE                                      
                    Thomas P. Burke
                     President and Chief Executive Officer and Director

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed by the following persons on behalf of the Registrant and in the capacities and on the date indicated.
                Signatures
 
                Title
 
           Date
 
 
 
 
 
/s/     THOMAS P. BURKE      
          Thomas P. Burke
 
President and Chief Executive Officer and Director
 
February 21, 2020
 
 
 
 
 
/s/     CARL G. TROWELL               
          Carl G. Trowell
 
Executive Chairman
 
February 21, 2020
 
 
 
 
 
/s/     WILLIAM E. ALBRECHT        
          William E. Albrecht 
 
Independent Lead Director
 
February 21, 2020
 
 
 
 
 
/s/     FREDERICK ARNOLD             
          Frederick Arnold
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     MARY E. FRANCIS CBE   
          Mary E. Francis CBE
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     GEORGES J. LAMBERT         
         Georges J. Lambert
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     SUZANNE P. NIMOCKS         
          Suzanne P. Nimocks
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     THIERRY PILENKO        
         Thierry Pilenko
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     KEITH O. RATTIE            
         Keith O. Rattie
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     PAUL E. ROWSEY, III             
         Paul E. Rowsey, III
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     CHARLES L. SZEWS      
          Charles L. Szews
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     ADAM WEITZMAN      
          Adam Weitzman
 
Director
 
February 21, 2020
 
 
 
 
 
/s/     JONATHAN H. BAKSHT       
          Jonathan H. Baksht
 
Executive Vice President and
    Chief Financial Officer
    (principal financial officer)
 
February 21, 2020
 
 
 
 
 
/s/     TOMMY E. DARBY  
          Tommy E. Darby
 
Vice President - Finance (principal accounting officer)
 
February 21, 2020

181


Exhibit 4.42

Description of the Company’s Class A Ordinary Shares Registered
Under Section 12 of the Exchange Act of 1934
The following summary of Valaris plc’s (the “Company” or “Valaris”) Class A Ordinary Shares is based on and qualified by the Company’s Articles of Association (the “Articles”). For a complete description of the terms and provisions of the Company’s equity securities, including its Class A Ordinary Shares, refer to the Articles, which are filed as an exhibit to this Annual Report on Form 10-K, and the relevant provisions of applicable law.
General
All of the issued Class A Ordinary Shares are fully paid and not subject to any further calls by the Company.
Class A Ordinary Shares carry the right to receive dividends or other distributions paid by Valaris.
The holders of Class A Ordinary Shares have the right to receive notice of, and to attend and vote at, all general meetings of Valaris.
Subject to the U.K. Companies Act 2006 (the “Companies Act”), any equity securities issued by Valaris for cash must first be offered to Valaris shareholders in proportion to their existing holdings of Class A Ordinary Shares unless waived by a special resolution of Valaris shareholders, either generally or specifically, for a maximum period not exceeding five years.
Class A Ordinary Shares are not redeemable; however, subject to the Companies Act, Valaris may purchase or contract to purchase any of its Class A Ordinary Shares off-market. Valaris may only purchase its Class A Ordinary Shares out of distributable reserves or the proceeds of a new issue of shares made for the purpose of funding the repurchase.
If Valaris is wound up (whether the liquidation is voluntary, under supervision of a court or by a court), the liquidator is under a duty to collect in and realize the assets of Valaris and to distribute them to creditors of Valaris and, if there is a surplus, to Valaris shareholders according to their entitlements. This applies whether the assets consist of property of one kind or of different kinds.
Under the Companies Act, a “special resolution” of shareholders requires the affirmative vote of not less than 75% of votes cast and an “ordinary resolution” requires the affirmative vote of greater than 50% of votes cast.

Share Capital
All of the issued Class A Ordinary Shares, nominal value US$0.40 per share, are fully paid and are not subject to any further calls by Valaris. There are no conversion rights, redemption provisions or sinking fund provisions relating to any Class A Ordinary Shares; however, subject to the Companies Act, Valaris may purchase or contract to purchase any of its Class A Ordinary Shares off-market.
Under English law, persons who are neither residents nor nationals of the U.K. may freely hold, vote and transfer the Valaris shares in the same manner and under the same terms as U.K. residents or nationals.
The Class A Ordinary Shares and the Class B Ordinary Shares, nominal value US$1.00 per share (collectively, the “Ordinary Shares”), have the same rights and privileges in all respects. While the Class B Ordinary Shares (all of which are held by a subsidiary of Valaris) remain in issue, such shares have no voting rights or rights to dividends or distributions, to the extent that they are held by Valaris or any of its subsidiaries.
Dividends
Subject to the Companies Act, the board of directors of Valaris (the “Valaris Board”) may resolve to pay a dividend to the shareholders according to their respective rights and interests in Valaris, and may fix the time for payment of such dividend. The Valaris Board may from time to time resolve to pay (on any class of shares of any amounts) such dividends as appear to them to be justified by the profits of Valaris that are available for distribution. When evaluating dividend payment timing and amounts, the Valaris Board considers several factors, including Valaris’s profitability, liquidity, financial condition, market outlook, reinvestment opportunities, capital requirements and other factors and restrictions the Valaris Board deems relevant. There can be no assurance that Valaris will pay a dividend in the future.





There are no fixed dates on which entitlement to dividends arise on any of the Ordinary Shares. The Valaris Board may direct the payment of all or any part of a dividend to be satisfied by distributing specific assets, in particular paid up shares or debentures of any other company. The Articles permit a scrip dividend scheme under which shareholders may be given the opportunity to elect to receive fully paid Class A Ordinary Shares instead of cash, with respect to all or part of future dividends. Ordinary Shares held by or for the benefit of a Valaris subsidiary will not be entitled to any dividends or distributions, including any scrip dividends, bonus shares or dividends or distributions of property or debentures of any other company. Further, the trustees of an employee benefit trust established in connection with Valaris’s equity incentive plans are not entitled to any dividends or distributions, including any scrip dividends, bonus shares or dividends or distributions of property or debentures of any other company.
If a shareholder owes any money to Valaris relating in any way to any class of Valaris shares, the Valaris Board may deduct any of this money from any dividend on any shares held by the shareholder, or from other money payable by Valaris in respect of the shares. Money deducted in this way may be used to pay the amount owed to Valaris.
Unclaimed dividends and other amounts payable by Valaris in respect of an Ordinary Share can be invested or otherwise used by the directors for the benefit of Valaris until they are claimed under English law. A dividend or other money remaining unclaimed for a period of twelve years after it first became due for payment will be forfeited and cease to remain owed by Valaris.

Voting Rights
At a general meeting of Valaris shareholders, any resolution put to a vote must be decided on a poll rather than by a show of hands.
Each Valaris shareholder (other than any of its subsidiaries who hold Ordinary Shares) who (being an individual) is present in person or (being a corporation) is present by a duly authorized corporate representative at Valaris’s general meeting will have one vote for every share held, and every person present who has been appointed as a proxy has one vote for every share in respect of which he or she is the proxy, except that any proxy who has been appointed by DTC or its proxies have such number of votes as equals the number of shares in relation to which such proxy has been appointed, subject to any rights or restrictions as to voting attached to any class of shares in accordance with the Articles or by agreement and subject to the disenfranchisement (i) in the event of non-payment of any call or other sum due and payable in respect of any shares not fully paid; (ii) in the event of any non-compliance with any statutory notice requiring disclosure of an interest in shares; and (iii) with respect to any shares held by the trustees of an employee benefit trust established in connection with Valaris’s equity incentive plans in which a beneficial interest has not yet vested in a beneficiary of such trust.
In the case of joint holders, the vote of the person whose name stands first in the register of shareholders and who tenders a vote, whether in person or by proxy, is accepted to the exclusion of any votes tendered by any other joint holders.
The necessary quorum for a general meeting is the shareholders who together represent at least the majority of the voting rights of all the shareholders entitled to vote present in person or by proxy (that is, any shares whose voting rights have been disenfranchised (whether pursuant to the Companies Act and/or under the Articles) shall be disregarded for the purposes of determining a quorum).
An annual general meeting of shareholders must be called by not less than 21 clear days’ notice and no more than 60 clear days’ notice. For all other general meetings except general meetings properly requisitioned by shareholders, such meetings may be called by not less than 14 clear days’ notice and no more than 60 days’ notice. The notice of meeting also must specify a time (which may not be more than 60 clear days nor less than 10 days before the date for the holding of the meeting) by which a person must be entered on the register in order to have the right to attend or vote at the meeting. The number of shares then registered in their respective names shall determine the number of votes a person is entitled to cast at that meeting.
Valaris must receive an appointment of proxy (whether in hard copy form or electronic form) before the time for holding the meeting or adjourned meeting at which the person named in the appointment of proxy proposes to vote; in the case of a poll taken more than 48 hours after the meeting at which the relevant vote was to be taken, an appointment





of proxy must be received after such meeting and not less than 24 hours (or such shorter time as the Valaris Board may determine) before the time appointed for taking the poll; or in the case of a poll not taken immediately but taken not more than 48 hours after the meeting, the appointment of proxy must be delivered at the meeting at which the poll is to be taken. An appointment of proxy not received or delivered in accordance with the Articles is invalid under English law.
Return of Capital
In the event of a voluntary winding-up of Valaris, the liquidator may, on obtaining any sanction required by law, divide among the shareholders the whole or any part of the assets of Valaris, whether or not the assets consist of property of one kind or of different kinds.
The liquidator also may, with the same authority, transfer the whole or any part of the assets to trustees upon any trusts for the benefit of the shareholders as the liquidator decides. No past or present shareholder can be compelled to accept any asset that could subject him or her to a liability.

Preemptive Rights and New Issues of Ordinary Shares
Under Section 549 of the Companies Act, directors are, with certain exceptions, unable to allot securities without being authorized either by the shareholders in a general meeting or by the Articles pursuant to Section 551 of the Companies Act. In addition, under the Companies Act, the issuance of equity securities that are to be paid for wholly in cash (except shares held under an employees’ share scheme) must be offered first to the existing equity shareholders in proportion to the respective nominal values of their holdings on the same or more favorable terms, unless a special resolution to the contrary has been passed in a general meeting of shareholders or the articles of association otherwise provide an exclusion from this requirement (which exclusion can be for a maximum of five years after which shareholders’ approval would be required to renew the exclusion). In this context, equity securities generally means ordinary shares (being shares other than shares that, with respect to dividends or capital, carry a right to participate only up to a specified amount in a distribution) and all rights to subscribe for or convert securities into such shares.
Subject to the provisions of the Companies Act and to any rights attached to any existing shares, any Valaris shares may be issued with, or have attached to them, such rights or restrictions as the shareholders of Valaris may by ordinary resolution determine, or, where the above authorizations are in place, the Valaris Board may determine such rights or restrictions.
The Companies Act prohibits an English company from issuing shares for no consideration, including with respect to grants of restricted shares made pursuant to equity incentive plans. Accordingly, the nominal value of the shares issued upon the lapse of restrictions or the vesting of any restricted share award or any other share-based grant must be paid pursuant to the Companies Act.
Disclosure of Interests in Shares
Section 793 of the Companies Act provides Valaris the power to require a person whom it knows has, or whom it has reasonable cause to believe has, or within the previous three years has had, any ownership interest in any shares (the “default shares”) to disclose prescribed particulars of those shares. For this purpose default shares includes any shares allotted or issued after the date of the Section 793 notice in respect of those shares. Failure to provide the information requested within the prescribed period after the date of sending the notice will result in sanctions being imposed against the holder of the “default shares” as provided within the Companies Act.
Under the Articles, Valaris also will withdraw voting and certain other rights, place restrictions on the rights to receive dividends and transfer “default shares” if the relevant holder of “default shares” has failed to provide the information requested within 14 days after the date of sending the notice, depending on the level of the relevant shareholding (and unless the Valaris Board decides otherwise).

Alteration of Share Capital/Repurchase of Ordinary Shares
Valaris may from time to time:





increase its share capital by allotting new shares in accordance any unused portion of any authority to allot shares approved by Valaris shareholders and in accordance with the Articles;
by ordinary resolution of its shareholders, consolidate and divide all or any of its share capital into shares of a larger nominal amount than the existing shares; and
by ordinary resolutions of its shareholders, subdivide any of its shares into shares of a smaller nominal amount than its existing shares.
 Subject to the Companies Act 2006 (including approval by Valaris’s shareholders by way of ordinary resolution) and to any rights the Valaris shareholders may have, Valaris may purchase Ordinary Shares by way of “off-market purchases. Such purchases are subject to various restrictions, including those imposed pursuant to the terms of relevant shareholder approvals, such as caps on both: (i) the number of Ordinary Shares that Valaris may purchase; and (ii) the aggregate financial cost of such purchases. Relevant shareholder approvals may last for up to five years from the date of the relevant ordinary resolution, and renewal of such approvals for additional five year terms may be sought. Valaris shares may only be repurchased out of distributable profits or the proceeds of a fresh issue of shares made for that purpose, and, if a premium is paid, it must be paid out of distributable profits.
Transfer of Ordinary Shares
The Articles allow Valaris’s shareholders to transfer all or any of their shares in any form that is approved by the Valaris Board.
The Valaris Board may refuse to register a transfer:
if the shares in question are not fully paid;
if it is with respect to more than one class of shares;
if it is with respect to shares on which Valaris has a lien;
if it is in favor of more than four persons jointly;
if, where an instrument of transfer is required to effect the transfer, and that instrument is required to be stamped, Her Majesty’s Revenue and Customs has not duly stamped it;
if it is not presented for registration together with the share certificate and evidence of title as the Valaris Board reasonably requires; or
in certain circumstances, if the holder has failed to provide the required particulars to Valaris as described under “Disclosure of Interests in Ordinary Shares” above.

Shareholders are strongly encouraged to hold their Class A Ordinary Shares in book entry form through the facilities of DTC, which may be achieved by instructing the delivery of such Class A Ordinary Shares to a bank or brokerage account or by appointing Computershare as custodian for such Class A Ordinary Shares. Transfers of Class A Ordinary Shares held in book entry form through DTC will not attract a charge to stamp duty or Stamp Duty Reserve Tax (“SDRT”) in the U.K. A transfer of title in the Class A Ordinary Shares from within the DTC system out of DTC and any subsequent transfers that occur entirely outside the DTC system, including repurchase by Valaris, may attract a stamp duty (currently 0.5%), which is payable by the transferee of the Class A Ordinary Shares. Any such duty must be paid (and the relevant transfer document stamped by HMRC, if applicable) before the transfer can be registered in the books of Valaris. In addition, if those Class A Ordinary Shares are redeposited into DTC, the redeposit will attract stamp duty or SDRT. Valaris has put in place arrangements to require that Class A Ordinary Shares held in certificated form cannot be transferred into the DTC system until the transferor of the Class A Ordinary Shares has first delivered the Class A Ordinary Shares to a depository specified by Valaris so that SDRT may be collected in connection with the initial delivery to the depository. Any such Class A Ordinary Shares will be evidenced by a receipt issued by the depository. Before the transfer can be registered in the books of Valaris, the transferor also will be required to put the depository in funds to settle the resultant liability to SDRT, which is currently 1.5% of the value of the Class A Ordinary Shares, and to pay the transfer agent such processing fees as may be established from time to time.
If the Valaris Board refuses to register a transfer of a share, it must, within two months after the date on which the transfer was lodged, send to the transferee notice of the refusal, together with its reasons for refusal. An instrument of transfer which the Valaris Board refuses to register must (except in the case of suspected fraud) be returned to the person depositing it.





General Meetings and Notices
The notice of a general meeting of shareholders must be given to the shareholders of record (other than any who, under the provisions of the Articles or the terms of allotment or issue of shares, are not entitled to receive notice), to the Valaris Board and to its auditors.
Under English law, Valaris is required to hold an annual general meeting of shareholders within six months from the day following the end of its fiscal year and, subject to the foregoing, the meeting may be held at a time and place determined by the Valaris Board.
Liability of Valaris’s Directors and Officers
The Articles provide that English courts have exclusive jurisdiction with respect to any suits brought by shareholders against Valaris or its directors. English law does not permit a company to exempt any director or certain officers from any liability arising from negligence, default, breach of duty or breach of trust against the company. However, despite this prohibition, an English company is permitted to purchase and maintain insurance for a director or executive officer of the company against any such liability. Valaris has entered into deeds of indemnity with each of its current directors and executive officers and purchased insurance on their behalf. In addition, directors and executive officers may be covered by indemnification agreements and indemnification rights granted under the charter documents of Valaris subsidiaries. Shareholders can ratify by ordinary resolution a director’s or certain officer’s conduct amounting to negligence, default, breach of duty or breach of trust in relation to the company.
Takeover Code
Takeover offers and certain other transactions in respect of certain public companies are regulated by the U.K. City Code on Takeovers and Mergers (the “Takeover Code”), which is administered by the Takeover Panel, a body consisting of representatives of the City of London financial and professional institutions that oversees the conduct of takeovers. An English public limited company potentially is subject to the Takeover Code if, among other factors, its central place of management and control is within the U.K., the Channel Islands or the Isle of Man. The Takeover Panel generally will look to the residency of a company’s directors to determine where it is centrally managed and controlled. The Takeover Panel has previously confirmed that on the basis of Valaris’s current directors and management the Takeover Code would not apply to Valaris. It is possible, however, that if the characteristics of Valaris’s directors or management were to change in the future the Takeover Panel may take a different position and the Takeover Code may apply to Valaris.
Anti-Takeover Provisions
General
The provisions of the Articles summarized below may have the effect of discouraging, delaying or preventing hostile takeovers, including those that might result in a premium being paid over the market price of Valaris’s Ordinary Shares and discouraging, delaying or preventing changes of control or management of Valaris.
Issuance of Additional Ordinary Shares
Subject to the terms of any then existing shareholder approvals (which are required by the Companies Act and which cannot endure for more than five years from the date of grant), the Valaris Board has the authority, without further action of Valaris’s shareholders, but subject to its statutory and fiduciary duties, to allot shares, or to grant rights to subscribe for or to convert or exchange any security into shares, up to a specified aggregate nominal amount, and to exclude preemptive rights in respect of certain issuances. The issuance of further shares on various terms could adversely affect the Valaris shareholders. The potential issuance of further Ordinary Shares may discourage bids for Ordinary Shares at a premium over the market price, may adversely affect the market price of Ordinary Shares and may discourage, delay or prevent a change of control.
Shareholder Rights Plan





The Valaris Board has the necessary corporate authority to exercise any power of the company to establish a shareholders rights plan. Any shareholders rights plan may be in such form as the Valaris Board may in its absolute discretion decide. Such a plan could make it more difficult for another party to obtain control of Valaris by threatening to dilute a potential acquirer’s ownership interest under certain circumstances. The Valaris Board may adopt a shareholder rights plan at any time.
The anti-takeover and other provisions of the Articles, as well as the adoption of a shareholder rights plan, could discourage potential acquisition proposals and could delay or prevent a change of control. These provisions are intended to enhance shareholder value by discouraging certain types of abusive takeover tactics. However, these provisions could have the effect of discouraging others from making tender offers for Class A Ordinary Shares and, as a consequence, also may inhibit fluctuations in the market price of Class A Ordinary Shares that could result from actual or rumored takeover attempts.

Board of Directors

At every annual general meeting all Valaris directors must retire from office and each director may offer himself or herself for re-appointment by the members. Under English law, shareholders have no cumulative voting rights. In addition, the Articles incorporate provisions that regulate shareholders’ ability to nominate directors for election. Although Valaris’s shareholders have the ability to remove a director without cause under English law, the lack of cumulative voting and the limitations on shareholders’ powers to nominate directors will have the effect of making it more difficult not only for any party to obtain control over Valaris by replacing the majority of the Valaris Board but also to force an immediate change in the composition of the Valaris Board. However, under the Articles, if Valaris shareholders remove the entire Valaris Board, a shareholder may then convene a general meeting for the purpose of appointing directors.




Exhibit 4.43

Description of the 4.70% Senior Notes due 2021 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “- Definitions” and in other parts of this description.
General
    The notes mature on March 15, 2021 and bear interest at 4.700% per year. We:
pay interest semiannually on March 15 and September 15 of each year;
pay interest to the person in whose name a note is registered at the close of business on the March 1 or September 1 preceding the Interest Payment Date;
compute interest on the basis of a 360-day year consisting of twelve 30-day months;
make payments on the notes at the offices of the trustee and any Paying Agent; and
make payments by wire transfer for notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.

We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
    The notes are limited to $1,500,000,000 in aggregate principal amount. We may, however, “reopen” the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders.
Optional Redemption
    The notes are redeemable, in whole at any time or in part from time to time, at our option at a redemption price equal to the greater of:
(i)
100% of the principal amount of the notes to be redeemed; and
(ii)
the sum of the present values of the remaining scheduled payments of principal and interest thereon (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below), plus 25 basis points, plus accrued interest thereon to the date of redemption. Notwithstanding the foregoing, installments of interest that are due and payable on Interest Payment Dates falling on or prior to a redemption date will be payable on the Interest Payment Date to the registered holders as of the close of business on the relevant record date according to the notes and the indenture.

    Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
    Comparable Treasury Price” means, with respect to any redemption date, (i) the average of three Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than five such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
    Quotation Agent” means the Reference Treasury Dealer appointed by us.





    Reference Treasury Dealer” means each of Citigroup Global Markets Inc., Deutsche Bank Securities Inc. (or their respective affiliates that are Primary Treasury Dealers), and a Primary Treasury Dealer (as defined herein) selected by Wells Fargo Securities, LLC and their respective successors and three other nationally recognized investment banking firms that are primary U.S. Government securities dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City, which we refer to as a Primary Treasury Dealer, we will substitute therefor another Primary Treasury Dealer.
    Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
    Treasury Rate” means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
    Notice of any redemption described under “- Optional Redemption” will be mailed at least 30 days but not more than 60 days before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by The Depository Trust Company, in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with the procedures of DTC, in the case of notes that are not represented by a global security.
We may at any time purchase notes on the open market or otherwise at any price. We will surrender all notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
Ranking
The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
    We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and foreign Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries. As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries’ financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
Additional Amounts
    All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, “Taxes”) unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the Paying Agent or any department or political subdivision thereof or therein (each, a “Tax Jurisdiction”) will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts (the “Additional Amounts”) as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional





Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; provided, however, that no Additional Amounts will be payable with respect to:
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof), this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
any estate, inheritance, gift, transfer, personal property or similar Tax;
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes;
any Taxes required to be withheld in respect of a payment of interest to an individual pursuant to the European Union Directive on the Taxation of Savings Income in the form of Interest Payments (Directive 2003/48/EC) on the taxation of savings income or any law implementing or complying with, or introduced in order to conform to, such Directive;
any Taxes required to be withheld in respect of a payment of interest in respect of notes presented for payment by or on behalf of a holder who would be able to avoid such withholding or deduction by presenting the relevant note to another Paying Agent in a Member State of the European Union; or
any combination of the above items.

We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to tax and other liabilities related thereto) which are levied by any Tax Jurisdiction on the execution, delivery, issuance, or registration of any of the notes, the indenture or any other document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary to enable the Paying Agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.





We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the Paying Agent of Additional Amounts, if applicable.

The above obligations will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business for tax purposes or any jurisdiction from or through which such Person or its Paying Agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.
Redemption for Changes in Taxes
We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days’ prior written notice to the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
any amendment to, or change in, the laws, tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after March 8, 2011 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after March 8, 2011, such later date); or
any amendment to, or change in, an official interpretation or application regarding such laws, tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective after March 8, 2011 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after March 8, 2011, such later date).

We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
Restrictive Covenants
Limitation on Liens
We will not, and will not permit any of our Subsidiaries to, incur, issue or assume any Indebtedness for borrowed money secured by any Lien upon any Principal Property or any shares of stock or Indebtedness of any Subsidiary that owns or leases a Principal Property (whether such Principal Property, shares of stock or Indebtedness are now owned or hereafter acquired) without making effective provision whereby the notes (together with, if we so determine, any other Indebtedness or other obligation of us or any Subsidiary) shall be secured equally and ratably with (or, at the option of us, prior to) the Indebtedness so secured by a Lien on the same assets of us or such Subsidiary, as the case may be, for so long as such Indebtedness is so secured. The foregoing restrictions will not, however, apply to Indebtedness secured by Permitted Liens.
Notwithstanding the foregoing, we and our Subsidiaries may, without securing the notes, incur, issue or assume Indebtedness that would otherwise be subject to the foregoing restrictions in an aggregate principal amount that, together with all other such Indebtedness of us and our Subsidiaries that would otherwise be subject to the foregoing restrictions (not including Indebtedness permitted to be secured under the definition of Permitted Liens) and the aggregate amount of Attributable Indebtedness deemed outstanding with respect to Sale/Leaseback Transactions (other than Sale/Leaseback Transactions in connection with which we have voluntarily retired any of the notes, any Pari





Passu Indebtedness or any Funded Indebtedness pursuant to clause (i) of the third bullet below under “Limitation on Sale Leaseback Transactions”) does not at any one time exceed 15% of Consolidated Net Tangible Assets.
For purposes of this covenant, if at the time any Indebtedness is incurred, issued or assumed, such Indebtedness is unsecured but is later secured by a Lien, such Indebtedness shall be deemed to be incurred at the time that such Indebtedness is so secured by a Lien.
Limitation on Sale Leaseback Transactions
So long as the notes are outstanding, we will not, and we will not permit any Subsidiary to, sell or transfer (other than to us or a Wholly Owned Subsidiary) any Principal Property, whether owned at the date of the indenture or thereafter acquired, which has been in full operation for more than 120 days prior to such sale or transfer, with the intention of entering into a lease of such Principal Property (except for a lease for a term, including any renewal thereof, of not more than three years), if after giving effect thereto the Attributable Indebtedness in respect of all such sale and leaseback transactions involving Principal Properties shall be in excess of 15% of Consolidated Net Tangible Assets.
Notwithstanding the foregoing, we or any Subsidiary may sell any Principal Property and lease it back if the net proceeds of such sale are at least equal to the fair value of such property as determined by our Board of Directors and,
we or such Subsidiary would be entitled to incur Indebtedness in a principal amount equal to the Attributable Indebtedness with respect to such Sale/Leaseback Transaction secured by a Lien on the property subject to such Sale/Leaseback Transaction pursuant to the covenant described under “Limitation on Liens” above without equally and ratably securing the notes pursuant to such covenant;
after the date of the indenture and within a period commencing nine months prior to the consummation of such Sale/Leaseback Transaction and ending nine months after the consummation thereof, we or such Subsidiary shall have expended for property used or to be used in the ordinary course of our business and that of our Subsidiaries an amount equal to all or a portion of the net proceeds of such Sale/Leaseback Transaction and we shall have elected to designate such amount as a credit against such Sale/Leaseback Transaction (with any such amount not being so designated to be applied as set forth in the following bullet or as otherwise permitted); or
we, during the nine-month period after the effective date of such Sale/Leaseback Transaction, shall have applied to either (i) the voluntary defeasance or retirement of any notes, any Pari Passu Indebtedness or any Funded Indebtedness or (ii) the acquisition of one or more Principal Properties at fair value, an amount equal to the greater of the net proceeds of the sale or transfer of the property leased in such Sale/Leaseback Transaction and the fair value, as determined by our Board of Directors, of such property as of the time of entering into such Sale/Leaseback Transaction (in either case adjusted to reflect the remaining term of the lease and any amount expended by us as set forth in the preceding bullet), less an amount equal to the sum of the principal amount of notes, Pari Passu Indebtedness and Funded Indebtedness voluntarily defeased or retired by us plus any amount expended to acquire any Principal Properties at fair value, within such nine month period and not designated as a credit against any other Sale/Leaseback Transaction entered into by us or any of our Subsidiaries during such period.

Consolidation, Merger and Sale of Assets
We will not, directly or indirectly, in any transaction or series of related transactions: (1) consolidate or merge with or into another Person (whether or not we are the surviving Person); (2) sell, assign, transfer, convey or otherwise dispose of all or substantially all of our and our Subsidiaries’ properties or assets taken as a whole, or (3) assign any of our obligations under the notes and the indenture, in one or more related transactions, to another Person; unless:
either: (A) we are the surviving or continuing Person; or (B) the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made is an Entity, validly organized and existing in good standing (to the extent the concept of good standing is applicable) under the laws of any state of the United States, the District of Columbia, the Cayman Islands, Bermuda, Switzerland, the United Kingdom, the





Kingdom of the Netherlands, the Grand Duchy of Luxembourg, Ireland, or any other member country of the European Union;
the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made assumes all our obligations under the notes and the indenture;
immediately after such transaction no Default or Event of Default exists; and
we shall have delivered to the trustee an Officers’ Certificate and an opinion of counsel, each stating that such merger, consolidation, amalgamation or sale, assignment, transfer, conveyance or other disposition of such properties or assets or assignment of our obligations under the notes and the indenture and such supplemental indenture, if any, comply with the indenture.

We will not, directly or indirectly, lease all or substantially all of our properties or assets, in one or more related transactions, to any other Person.
Notwithstanding the foregoing, the limitations described above shall not apply to a sale, assignment, transfer, conveyance or other disposition of assets between or among us and any of our Wholly Owned Subsidiaries.
Events of Default
An “Event of Default” on the notes occurs if:
(1)
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;

(2)
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;

(3)
we fail to comply with any of our other agreements in the notes or the indenture (as they relate thereto), which shall not have been remedied within the specified period after written notice, as specified below;

(4)
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or

(5)
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us, and the order or decree remains unstayed and in effect for 60 days.

    The term “Bankruptcy Law” means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term “Custodian” means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
    If any Event of Default (other than an Event of Default specified in clause (4) or (5) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (4) or (5) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice. The holders of a majority in aggregate principal amount of the notes then outstanding by notice to the trustee may on behalf of the holders of all





of the notes waive any existing Default or Event of Default and its consequences under the indenture except a continuing Default or Event of Default in the payment of interest or premium, if any, on, or the principal of, the notes.
Notwithstanding the foregoing a Default under clause (3) above is not an Event of Default until the trustee notifies us, or the holders of at least 25% in principal amount of the then outstanding notes notify us and the trustee, of the Default, and we fail to cure the Default within 90 days after receipt of the notice. The notice must specify the Default, demand that it be remedied and state that the notice is a “Notice of Default.”
Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (provided, however, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
Modification and Waiver
We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:
reduce the principal amount of the outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);
make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.

We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:
to cure any ambiguity, defect or inconsistency;
to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture described under “Consolidation, Merger and Sale of Assets”;
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such





amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof; and
to add a guarantor of the notes.

    The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to those notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
Defeasance and Discharge
    Defeasance. When we use the term “defeasance,” we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:
we will be discharged from our obligations with respect to the notes (“legal defeasance”); or
we will no longer have any obligation to comply with specified restrictive covenants with respect to the notes, the covenant described under “- Consolidation, Merger and Sales of Assets” and other specified covenants under the indenture, and the related Events of Default will no longer apply (“covenant defeasance”).

    If the notes are defeased, the holders of the notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.
We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the United States Internal Revenue Service or a change in law to that effect.
    Satisfaction and Discharge. In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:
either:
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and the Company, in the case of the three preceding bullets, has deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government





obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers’ Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to the notes have been complied with.
The Trustee
 
Deutsche Bank Trust Company Americas is the trustee under the indenture.  Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
 
The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.

Paying Agents and Transfer Agents
The trustee has been appointed as Paying Agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any Paying Agent. At our option, however, payments may be made by wire transfer for notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.
If the principal of or any premium or interest on the notes is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease.
Definitions
Attributable Indebtedness,” when used with respect to any Sale/Leaseback Transaction, means, as at the time of determination, the present value (discounted at the rate set forth or implicit in the terms of the lease included in such transaction) of the total obligations of the lessee for rental payments (other than amounts required to be paid on account of taxes, maintenance, repairs, insurance, assessments, utilities, operating and labor costs and other items which do not constitute payments for property rights) during the remaining term of the lease included in such Sale/Leaseback Transaction (including any period for which such lease has been extended). In the case of any lease which is terminable by the lessee upon the payment of a penalty, such net amount shall be the lesser of the net amount determined assuming termination upon the first date such lease may be terminated (in which case the net amount shall also include the amount of the penalty, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated) or the net amount determined assuming no such termination.
Bankruptcy Act” means the Bankruptcy Act or Title 11 of the United States Code, as amended.
Board of Directors” means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of the Board of Directors or comparable governing body.





Capitalized Lease Obligation” of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
Consolidated Net Tangible Assets” means the total amount of assets (after deducting applicable reserves and other properly deductible items) less:
all current liabilities (excluding liabilities that are extendible or renewable at our option to a date more than 12 months after the date of calculation and excluding current maturities of long-term Indebtedness); and
all goodwill, trade names, trademarks, patents, unamortized debt discount and expense and other like intangible assets.

We will calculate our Consolidated Net Tangible Assets based on our most recent quarterly balance sheet and in accordance with GAAP.
Default” means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
Entity” means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
Funded Indebtedness” means all Indebtedness that matures on or is renewable to a date more than one year after the date the Indebtedness is incurred.
GAAP” means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
Indebtedness” means:
all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby     letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn or, to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person’s legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.

Interest Payment Date” when used with respect to any note, means the Stated Maturity of an installment of interest on such note.
Issue Date” means March 17, 2011, the date on which the notes were first authenticated and delivered under the indenture.
Joint Venture” means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
Lien” means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired





or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
Maturity” when used with respect to any notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
Officers” means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
Officers’ Certificate” means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
Pari Passu Indebtedness” means any of our Indebtedness, whether outstanding on the Issue Date of the notes or thereafter created, incurred or assumed, unless, in the case of any particular Indebtedness, the instrument creating or evidencing the same or pursuant to which the same is outstanding expressly provides that such Indebtedness shall be subordinated in right of payment to the notes.
Paying Agent” means any Person, which may include us, authorized by us to pay the principal of (and premium, if any) or interest on any one or more series of notes on our behalf.
Permitted Liens” shall mean (i) Liens existing on the Issue Date; (ii) Liens on property or assets of, or any shares of stock of, or other equity interests in, or Indebtedness of, any Person existing at the time such Person becomes a Subsidiary of us or at the time such Person is merged into or consolidated with us or any of our Subsidiaries or at the time of a sale, lease or other disposition of the properties of a Person (or a division thereof) as an entirety or substantially as an entirety to us or a Subsidiary, and not incurred in contemplation of such merger, consolidation, sale, lease or other disposition; (iii) Liens in favor of us or any of our Subsidiaries or Liens securing debt of a Subsidiary owing to the Company or to another Subsidiary; (iv) Liens in favor of governmental bodies to secure partial, progress, advance or other payments or performance pursuant to the provisions of any contract or statute; (v) Liens securing industrial revenue, pollution control or similar revenue bonds; (vi) Liens on assets existing at the time of acquisition thereof, securing all or any portion of the cost of acquiring, constructing, improving, developing, expanding or repairing such assets or securing Indebtedness incurred prior to, at the time of, or within 24 months after, the later of the acquisition, the completion of construction, improvement, development, expansion or repair or the commencement of commercial operation of such assets, for the purpose of (a) financing all or any part of the purchase price of such assets or (b) financing all or any part of the cost of construction, improvement, development, expansion or repair of any such assets; (vii) statutory liens or landlords’, carriers’, warehouseman’s, mechanics’, suppliers’, materialmen’s, repairmen’s, maritime or other like Liens arising in the ordinary course of business and with respect to amounts not yet delinquent or being contested in good faith by appropriate proceedings; (viii) Liens in connection with in rem and other legal proceedings, which are being contested in good faith; (ix) Liens securing taxes, assessments, government charges or levies not yet due or delinquent, or which can thereafter be paid without penalty, or which are being contested in good faith by appropriate proceedings; (x) Liens on the stock, partnership or other equity interest of us or any Subsidiary in any Joint Venture or any Subsidiary that owns an equity interest in such Joint Venture to secure Indebtedness, provided the amount of such Indebtedness is contributed and/or advanced solely to such Joint Venture; (xi) Liens incurred in the ordinary course of business to secure performance of tenders, bids or contracts entered into in the ordinary course of business, including without limitation any rights of offset or liquidated damages, penalties, or other fees that may be contractually agreed to in conjunction with any tender, bid, or contract entered into by us or any of our Subsidiaries in the ordinary course of business; (xii) Liens on current assets of us or any of our Subsidiaries securing our Indebtedness or Indebtedness of any such Subsidiary, respectively; (xiii) deposits made in connection with maintaining self-insurance, to obtain the benefits of laws, regulations or arrangements relating to unemployment insurance, old age pensions, social security or similar matters or to secure surety, appeal or customs bonds; and (xiv) any extensions, substitutions, replacements or renewals in whole or in part of a Lien enumerated in clauses (i) through (xiii) above, provided that the amount of Indebtedness secured by such extension, substitution, replacement or renewal shall not exceed the principal amount of Indebtedness being substituted, extended, replaced or renewed, together with the amount of any premiums, fees, costs and expenses associated with such substitution, extension, replacement or renewal, nor shall the pledge, mortgage or lien be extended to any additional Principal Property unless otherwise permitted under the covenant described under “Limitation on Liens.”





Person” means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
Principal Property” means any drilling rig or drillship, or integral portion thereof, owned or leased by us or any Subsidiary and used for drilling offshore oil and gas wells, which, in the opinion of the Board of Directors, is of material importance to the business of us and our Subsidiaries taken as a whole, but no such drilling rig or drillship, or portion thereof, shall be deemed of material importance if its net book value (after deducting accumulated depreciation) is less than 2% of Consolidated Net Tangible Assets.
Sale/Leaseback Transaction” means any arrangement with any Person pursuant to which we or any Subsidiary leases any Principal Property that has been or is to be sold or transferred by us or the Subsidiary to such Person, other than (1) temporary leases for a term, including renewals at the option of the lessee, of not more than five years; (2) leases between us and a Subsidiary or between Subsidiaries; and (3) leases of Principal Property executed by the time of, or within 12 months after the latest of, the acquisition, the completion of construction, alteration, improvement or repair, or the commencement of commercial operation of the Principal Property.
    Stated Maturity” when used with respect to any note or any installment of principal thereof or interest thereon, means the date specified in such note as the fixed date on which the principal of such note or such installment of principal or interest is due and payable.
Subsidiary” means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.
    Voting Stock” means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.
    Wholly Owned Subsidiary” means, with respect to a Person, any Subsidiary of that Person to the extent
all of the Voting Stock of such Subsidiary, other than any director’s qualifying shares mandated by applicable law, is owned directly or indirectly by such Person or

such Subsidiary is organized in a foreign jurisdiction and is required by the applicable laws and regulations of such foreign jurisdiction to be partially owned by another Person, if such Person:
directly or indirectly owns the remaining capital stock of such Subsidiary and
by contract or otherwise, controls the management and business of such Subsidiary and derives the economic benefits of ownership of such Subsidiary to substantially the same extent as if such Subsidiary were a Wholly Owned Subsidiary.




Exhibit 4.44

Description of the 4.50% Senior Notes due 2024 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “Definitions” and in other parts of this description.
General
        The notes will mature on October 1, 2024 and will bear interest at 4.50% per year. We:
pay interest semiannually on April 1 and October 1 of each year;
pay interest to the person in whose name a note is registered at the close of business on the March 15 or September 15 preceding the interest payment date;
compute interest on the basis of a 360-day year consisting of twelve 30-day months;
make payments on the notes at the offices of the trustee and any paying agent; and
may make payments by wire transfer for notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.
        We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
        The notes are limited to $625,000,000 in aggregate principal amount. We may, however, "reopen" the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders.
Optional Redemption
        We may redeem the notes, in whole at any time or in part from time to time, prior to their maturity. If we elect to redeem the notes before July 1, 2024, we will pay a redemption price equal to the greater of:
100% of the principal amount of the notes to be redeemed; and
the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the notes matured on the applicable Par Call Date (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below), plus 30 basis points, plus accrued interest thereon to the date of redemption.
If we elect to redeem the notes on or after the Par Call Date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued interest thereon to the date of redemption.
        Notwithstanding the foregoing, installments of interest on the notes being redeemed that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date according to the notes and the indenture.
        "Comparable Treasury Issue" means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes (assuming, for this purpose, that such notes matured on the applicable Par Call Date) to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
        "Comparable Treasury Price" means, with respect to any redemption date, (i) the average of two Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.





        "Par Call Date" means July 1, 2024.
        "Quotation Agent" means the Reference Treasury Dealer appointed by us.
        "Reference Treasury Dealer" means each of Citigroup Global Markets Inc., Deutsche Bank Securities Inc. (or their respective affiliates that are Primary Treasury Dealers (as defined below)) and their respective successors and two other nationally recognized investment banking firms that are primary U.S. Government securities dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), we will substitute therefor another Primary Treasury Dealer.
        "Reference Treasury Dealer Quotations" means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
        "Treasury Rate" means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
        Notice of any redemption described under "Optional Redemption" will be mailed at least three business days (provided that the trustee has received drafts of such notice at least five days in advance thereof, or such shorter period as is satisfactory to the trustee) but not more than 60 days before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by The Depository Trust Company ("DTC"), in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with any applicable procedures of DTC, in the case of notes that are not represented by a global security.
        We may at any time purchase notes on the open market or otherwise at any price. We will surrender all notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
Ranking
        The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
        We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and non-U.S. Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries. As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries' financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
Additional Amounts
        All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, "Taxes") unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for Tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the paying agent or any department or political





subdivision thereof or therein (each, a "Tax Jurisdiction") will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts (the "Additional Amounts") as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; providedhowever, that no Additional Amounts will be payable with respect to:
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double Tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable Tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event that any such requirements are imposed as a result of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof) after the Issue Date, this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
any estate, inheritance, gift, transfer, personal property or similar Tax;
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes;
any Taxes required to be withheld pursuant to the EC Council Directive on the Taxation of Savings Income in the Form of Interest Payments (Directive 2003/48/EC) (as amended by EC Counsel Directive 2014/48/EU on March 24, 2014) or any law implementing or complying with, or introduced in order to conform to, such Directive or any agreement between the European Union and any non-EU jurisdiction providing for equivalent measures;
any Taxes required to be withheld in respect of a payment of interest in respect of notes presented for payment by or on behalf of a holder who would be able to avoid such withholding or deduction by presenting the relevant note to another paying agent in a member state of the European Union; or
any combination of the above items.
        We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
        In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to Tax and other liabilities related thereto) which are levied by any Tax Jurisdiction on the execution, delivery, issuance, or registration of any of the notes, the indenture or any other





document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
        If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary to enable the paying agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.
        We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
        Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the paying agent of Additional Amounts, if applicable.
        The obligations under this section will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business for Tax purposes or any jurisdiction from or through which such Person or its paying agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.

Redemption for Changes in Taxes
        We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days' prior written notice to the trustee and the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
any amendment to, or change in, the laws, Tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after September 24, 2014 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after September 24, 2014, such later date); or
any amendment to, or change in, an official interpretation or application regarding such laws, Tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective after September 24, 2014 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after September 24, 2014, such later date).
        We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
Events of Default
        An "Event of Default" on the notes occurs if:
(1)
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;
(2)
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;





(3)
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or
(4)
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us, and the order or decree remains unstayed and in effect for 60 days.
        The term "Bankruptcy Law" means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term "Custodian" means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
        If any Event of Default (other than an Event of Default specified in clause (3) or (4) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (3) or (4) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice.
        Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (providedhowever, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
Modification and Waiver
        We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:
reduce the principal amount of the outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of notes of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);
make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.
        We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:
to cure any ambiguity, defect or inconsistency;





to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture;
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof; and
to add a guarantor of the notes.
        The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to those notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
Defeasance and Discharge
        Defeasance.    When we use the term "defeasance," we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:
we will be discharged from our obligations with respect to notes ("legal defeasance"); or
we will no longer have any obligation to comply with any restrictive covenants with respect to the notes and the related Events of Default will no longer apply ("covenant defeasance").
        If the notes are defeased, the holders of the notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.
        We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the U.S. Internal Revenue Service or a change in law to that effect.
        Satisfaction and Discharge.    In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:
either
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and





held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and we, in the case of the three preceding bullets, have deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to the notes have been complied with.
The Trustee
        Deutsche Bank Trust Company Americas is the trustee under the indenture. Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
        The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.
Payment; Paying Agents and Transfer Agents
The trustee has been appointed as paying agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any paying agent. At our option, however, payments may be made by wire transfer for notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.
If the principal of or any premium or interest on notes of a series is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease.
Definitions
        "Bankruptcy Act" means the Bankruptcy Act or Title 11 of the United States Code, as amended.
        "Board of Directors" means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of our Board of Directors or comparable governing body.
        "Capitalized Lease Obligation" of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for





financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
        "Default" means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
        "Entity" means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
        "GAAP" means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
        "Indebtedness" means:
all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn or, to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person's legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.
        "Issue Date" means September 29, 2014, the date on which the notes were first authenticated and delivered under the indenture.
        "Joint Venture" means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Lien" means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
        "Maturity" when used with respect to any notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
        "Officers" means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
        "Officers' Certificate" means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
        "Person" means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
        "Stated Maturity" when used with respect to any note or any installment of principal thereof or interest thereon, means the date specified in such note as the fixed date on which the principal of such note or such installment of principal or interest is due and payable.
        "Subsidiary" means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.





        "Voting Stock" means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.




Exhibit 4.45

Description of the 8.00% Senior Notes due 2024 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “-Definitions” and in other parts of this description.
General
 
The notes mature on January 31, 2024 and bear interest at 8.00% per year. We:

pay interest semi-annually on January 31 and July 31 of each year;
pay interest to the person in whose name a note is registered at the close of business on the January 15 or July 15 preceding the interest payment date;
compute interest on the basis of a 360-day year consisting of twelve 30-day months;
make payments on the notes at the offices of the trustee and any paying agent; and
may make payments by wire transfer for the notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.
 
We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
 
We may “reopen” the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders, provided that such additional notes will not have the same CUSIP, ISIN or other identifying numbers as the outstanding notes unless such additional notes are fungible with the outstanding notes for U.S. federal income tax purposes.
  
Optional Redemption
 
We may redeem the notes, in whole at any time or in part from time to time, prior to their maturity. If we elect to redeem the notes before the Par Call Date, we will pay a redemption price equal to the greater of:
 
100% of the principal amount of the notes to be redeemed; and
the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the notes matured on the Par Call Date (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below) plus 50 basis points, plus accrued interest thereon to the date of redemption.
 
If we elect to redeem the notes on or after the Par Call Date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued interest thereon to the date of redemption.
 
Notwithstanding the foregoing, installments of interest on the notes being redeemed that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date according to such notes and the indenture.
 
Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes (assuming, for this purpose, that such notes matured on the





Par Call Date) to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
 
Comparable Treasury Price” means, with respect to any redemption date, (i) the average of two Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
 
Par Call Date” means October 31, 2023 (three months prior to the maturity date of the notes).
 
Quotation Agent” means the Reference Treasury Dealer appointed by us.
 
Reference Treasury Dealer” means each of Citigroup Global Markets Inc. and HSBC Securities (USA) Inc. (or their respective affiliates that are Primary Treasury Dealers (as defined below)) and their respective successors and two other nationally recognized investment banking firms that are Primary Treasury Dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a “Primary Treasury Dealer”), we will substitute therefor another Primary Treasury Dealer.
 
Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
 
Treasury Rate” means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
 
Notice of any redemption described under “-Optional Redemption” will be mailed at least 15 days but not more than 60 days before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by DTC, in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with any applicable procedures of DTC, in the case of notes that are not represented by a global security.
 
We may at any time purchase the notes on the open market or otherwise at any price. We will surrender all the notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
 
Ranking
 
The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
 
We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and non-U.S. Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries.  As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries’ financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior





position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
 
Additional Amounts
 
All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, “Taxes”) unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for Tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the paying agent or any department or political subdivision thereof or therein (each, a “Tax Jurisdiction”) will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts (the “Additional Amounts”) as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; provided, however, that no Additional Amounts will be payable with respect to:
 
(1)
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);
(2)
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double Tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable Tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event that any such requirements are imposed as a result of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof) after the Issue Date, this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
(3)
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
(4)
any estate, inheritance, gift, transfer, personal property or similar Tax;
(5)
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes; or
(6)
any combination of the above items.
 
We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
 
In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, stamp duty, stamp duty reserve tax, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to Tax and other liabilities related thereto) that





are levied by any Tax Jurisdiction on the execution, delivery, issuance or registration of any of the notes, the indenture or any other document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
 
If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary to enable the paying agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.
 
We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
 
Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the paying agent of Additional Amounts, if applicable.
 
The obligations under this section will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business for Tax purposes or any jurisdiction from or through which such Person or its paying agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.
 
Redemption for Changes in Taxes
 
We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days’ prior written notice to the trustee and the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
 
(7)
any amendment to, or change in, the laws, Tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after December 6, 2016 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after December 6, 2016, such later date); or
(8)
any amendment to, or change in, an official interpretation or application regarding such laws, Tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective after December 6, 2016  (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after December 6, 2016, such later date).
 
We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
 
Restrictive Covenants
 
Limitation on Liens
 





We will not, and will not permit any of our Subsidiaries to, incur, issue or assume any Indebtedness for borrowed money secured by any Lien upon any Principal Property or any shares of stock or Indebtedness of any Subsidiary that owns or leases a Principal Property (whether such Principal Property, shares of stock or Indebtedness are now owned or hereafter acquired) without making effective provision whereby the notes (together with, if we so determine, any other Indebtedness or other obligation of us or any Subsidiary) shall be secured equally and ratably with (or, at our option, prior to) the Indebtedness so secured by a Lien on the same assets of us or such Subsidiary, as the case may be, for so long as such Indebtedness is so secured. The foregoing restrictions will not, however, apply to Indebtedness secured by Permitted Liens.
 
Notwithstanding the foregoing, we and our Subsidiaries may, without securing the notes, incur, issue or assume Indebtedness that would otherwise be subject to the foregoing restrictions in an aggregate principal amount that, together with all other such Indebtedness of us and our Subsidiaries that would otherwise be subject to the foregoing restrictions (not including Indebtedness permitted to be secured under the definition of Permitted Liens) and the aggregate amount of Attributable Indebtedness deemed outstanding with respect to Sale/Leaseback Transactions (other than Sale/ Leaseback Transactions in connection with which we have voluntarily retired any of the notes, any Pari Passu Indebtedness or any Funded Indebtedness pursuant to clause (i) of the third bullet below under “Limitation on Sale Leaseback Transactions”) does not at any one time exceed 15% of Consolidated Net Tangible Assets.
 
For purposes of this covenant, if at the time any Indebtedness is incurred, issued or assumed, such Indebtedness is unsecured but is later secured by a Lien, such Indebtedness shall be deemed to be incurred at the time that such Indebtedness is so secured by a Lien.
 
Limitation on Sale/Leaseback Transactions
 
So long as the notes are outstanding, we will not, and we will not permit any Subsidiary to, sell or transfer (other than to us or a Wholly Owned Subsidiary) any Principal Property, whether owned at the date of the indenture or thereafter acquired, which has been in full operation for more than 120 days prior to such sale or transfer, with the intention of entering into a lease of such Principal Property (except for a lease for a term, including any renewal thereof, of not more than three years), if after giving effect thereto the Attributable Indebtedness in respect of all such sale and leaseback transactions involving Principal Properties shall be in excess of 15% of Consolidated Net Tangible Assets.
  
Notwithstanding the foregoing, we or any Subsidiary may sell any Principal Property and lease it back if the net proceeds of such sale are at least equal to the fair value of such property as determined by our Board of Directors and:

we or such Subsidiary would be entitled to incur Indebtedness in a principal amount equal to the Attributable Indebtedness with respect to such Sale/Leaseback Transaction secured by a Lien on the property subject to such Sale/Leaseback Transaction pursuant to the covenant described under “Limitation on Liens” above without equally and ratably securing the notes pursuant to such covenant;
after the Issue Date and within a period commencing nine months prior to the consummation of such Sale/Leaseback Transaction and ending nine months after the consummation thereof, we or such Subsidiary shall have expended for property used or to be used in the ordinary course of our business and that of our Subsidiaries an amount equal to all or a portion of the net proceeds of such Sale/Leaseback Transaction and we shall have elected to designate such amount as a credit against such Sale/Leaseback Transaction (with any such amount not being so designated to be applied as set forth in the following bullet or as otherwise permitted); or
 we, during the nine-month period after the effective date of such Sale/Leaseback Transaction, shall have applied to either (i) the voluntary defeasance or retirement of any notes, any Pari Passu Indebtedness or any Funded Indebtedness or (ii) the acquisition of one or more Principal Properties at fair value, an amount equal to the greater of the net proceeds of the sale or transfer of the property leased in such Sale/Leaseback Transaction and the fair value, as determined by our Board of Directors, of such property as of the time of entering into such Sale/Leaseback Transaction (in either case adjusted to reflect the remaining term of the lease and any amount expended by us as set forth in the preceding bullet), less an amount equal to the sum of the principal amount of the notes, Pari Passu Indebtedness and Funded Indebtedness voluntarily defeased or retired by us plus any amount expended to acquire any Principal Properties at fair value, within such nine month period





and not designated as a credit against any other Sale/Leaseback Transaction entered into by us or any of our Subsidiaries during such period.
 
Consolidation, Merger and Sale of Assets
 
We will not, directly or indirectly, in any transaction or series of related transactions: (1) consolidate or merge with or into another Person (whether or not we are the surviving Person); (2) sell, assign, transfer, convey or otherwise dispose of all or substantially all of our and our Subsidiaries’ properties or assets taken as a whole, or (3) assign any of our obligations under the notes and the indenture, in one or more related transactions, to another Person; unless:
 
either: (A) we are the surviving or continuing Person; or (B) the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made is an Entity, validly organized and existing in good standing (to the extent the concept of good standing is applicable) under the laws of any state of the United States, the District of Columbia, the Cayman Islands, Bermuda, Switzerland, the United Kingdom, the Kingdom of the Netherlands, the Grand Duchy of Luxembourg, Ireland, or any other member country of the European Union;
the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made assumes all our obligations under the notes and the indenture;
immediately after such transaction no Default or Event of Default exists; and
we shall have delivered to the trustee an Officers’ Certificate and an opinion of counsel, each stating that such merger, consolidation, amalgamation or sale, assignment, transfer, conveyance or other disposition of such properties or assets or assignment of our obligations under the notes and the indenture and such supplemental indenture, if any, comply with the indenture.
 
We will not, directly or indirectly, lease all or substantially all of our properties or assets, in one or more related transactions, to any other Person.
 
Notwithstanding the foregoing, the limitations described above shall not apply to a sale, assignment, transfer, conveyance or other disposition of assets between or among us and any of our Wholly Owned Subsidiaries.
 
Events of Default
 
An “Event of Default” on the notes occurs if:

1.
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;
2.
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;
3.
we fail to comply with any of our other agreements in the notes or the indenture (as they relate thereto), which shall not have been remedied within the specified period after written notice, as specified below;
4.
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or
5.
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us,
 
and the order or decree remains unstayed and in effect for 60 days.





 
The term “Bankruptcy Law” means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term “Custodian” means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
 
If any Event of Default (other than an Event of Default specified in clause (4) or (5) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (4) or (5) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice.
 
Notwithstanding the foregoing, a Default under clause (3) above is not an Event of Default until the trustee notifies us, or the holders of at least 25% in principal amount of the then outstanding notes notify us and the trustee, of the Default, and we fail to cure the Default within 90 days after receipt of the notice. The notice must specify the Default, demand that it be remedied and state that the notice is a “Notice of Default.”
 
Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal
 
of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (provided, however, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration, with respect to the notes). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
 
Modification and Waiver
 
We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:

reduce the principal amount of the then outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of the notes of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);
make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of the notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.
 
We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:

to cure any ambiguity, defect or inconsistency;





to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture described under “Consolidation, Merger and Sale of Assets”;
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of the notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof;
to add a guarantor of the notes; and
to conform any provision to the “Description of the New Notes” section of our Offering Memorandum, dated December 6, 2016, pursuant to the which the notes were originally offered.
The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to such notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
 
Defeasance and Discharge
 
Defeasance. When we use the term “defeasance,” we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:

we will be discharged from our obligations with respect to the notes (“legal defeasance”); or
we will no longer have any obligation to comply with specified restrictive covenants with respect to the notes, the covenant described under “-Consolidation, Merger and Sales of Assets” and other specified covenants under the indenture, and the related Events of Default will no longer apply (“covenant defeasance”).
 
If the notes are defeased, the holders of such notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.
 
We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the U.S. Internal Revenue Service or a change in law to that effect.
 
Satisfaction and Discharge. In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:






either:
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and we, in the case of the three preceding bullets, have deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers’ Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to such notes have been complied with.
 
The Trustee
 
Deutsche Bank Trust Company Americas is the trustee under the indenture.  Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
 
The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.

Payment; Paying Agents and Transfer Agents

The trustee has been appointed as paying agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any paying agent. At our option, however, payments may be made by wire transfer for the notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.

If the principal of or any premium or interest on the notes is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease. 









Definitions
 
Attributable Indebtedness,” when used with respect to any Sale/Leaseback Transaction, means, as at the time of determination, the present value (discounted at the rate set forth or implicit in the terms of the lease included in such transaction) of the total obligations of the lessee for rental payments (other than amounts required to be paid on account of taxes, maintenance, repairs, insurance, assessments, utilities, operating and labor costs and other items which do not constitute payments for property rights) during the remaining term of the lease included in such Sale/Leaseback Transaction (including any period for which such lease has been extended). In the case of any lease which is terminable by the lessee upon the payment of a penalty, such net amount shall be the lesser of the net amount determined assuming termination upon the first date such lease may be terminated (in which case the net amount shall also include the amount of the penalty, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated) or the net amount determined assuming no such termination.
 
Bankruptcy Act” means the Bankruptcy Act or Title 11 of the United States Code, as amended.
 
Board of Directors” means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of our Board of Directors or comparable governing body.
 
Capitalized Lease Obligation” of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
 
Consolidated Net Tangible Assets” means the total amount of assets (after deducting applicable reserves and other properly deductible items) less:

all current liabilities (excluding liabilities that are extendible or renewable at our option to a date more than 12 months after the date of calculation and excluding current maturities of long-term Indebtedness); and
all goodwill, trade names, trademarks, patents, unamortized debt discount and expense and other like intangible assets.
 
We will calculate our Consolidated Net Tangible Assets based on our most recent quarterly balance sheet and in accordance with GAAP.
 
Default” means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
 
Entity” means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
 
Funded Indebtedness” means all Indebtedness that matures on or is renewable to a date more than one year after the date the Indebtedness is incurred.
 
GAAP” means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
 
Indebtedness” means:

all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn or,





to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person’s legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.
 
Issue Date” means January 9, 2017, the date on which the notes were first authenticated and delivered under the indenture.
 
Joint Venture” means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
 
Lien” means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
 
Maturity” when used with respect to any notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
 
Officers” means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
 
Officers’ Certificate” means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
 
Pari Passu Indebtedness” means any of our Indebtedness, whether outstanding on the Issue Date or thereafter created, incurred or assumed, unless, in the case of any particular Indebtedness, the instrument creating or evidencing the same or pursuant to which the same is outstanding expressly provides that such Indebtedness shall be subordinated in right of payment to the notes.
 
Permitted Liens” shall mean (i) Liens existing on the Issue Date; (ii) Liens on property or assets of, or any shares of stock of, or other equity interests in, or Indebtedness of, any Person existing at the time such Person becomes a Subsidiary of us or at the time such Person is merged into or consolidated with us or any of our Subsidiaries or at the time of a sale, lease or other disposition of the properties of a Person (or a division thereof) as an entirety or substantially as an entirety to us or a Subsidiary, and not incurred in contemplation of such merger, consolidation, sale, lease or other disposition; (iii) Liens in favor of us or any of our Subsidiaries or Liens securing debt of a Subsidiary owing to us or to another Subsidiary; (iv) Liens in favor of governmental bodies to secure partial, progress, advance or other payments or performance pursuant to the provisions of any contract or statute; (v) Liens securing industrial revenue, pollution control or similar revenue bonds; (vi) Liens on assets existing at the time of acquisition thereof, securing all or any portion of the cost of acquiring, constructing, improving, developing, expanding or repairing such assets or securing Indebtedness incurred prior to, at the time of, or within 24 months after, the later of the acquisition, the completion of construction, improvement, development, expansion or repair or the commencement of commercial operation of such assets, for the purpose of (a) financing all or any part of the purchase price of such assets or (b) financing all or any part of the cost of construction, improvement, development, expansion or repair of any such assets; (vii) statutory liens or landlords’, carriers’, warehouseman’s, mechanics’, suppliers’, materialmen’s,





repairmen’s, maritime or other like Liens arising in the ordinary course of business and with respect to amounts not yet delinquent or being contested in good faith by appropriate proceedings; (viii) Liens in connection with in rem and other legal proceedings, which are being contested in good faith; (ix) Liens securing taxes, assessments, government charges or levies not yet due or delinquent, or which can thereafter be paid without penalty, or which are being contested in good faith by appropriate proceedings; (x) Liens on the stock, partnership or other equity interest of us or any Subsidiary in any Joint Venture or any Subsidiary that owns an equity interest in such Joint Venture to secure Indebtedness, provided the amount of such Indebtedness is contributed and/or advanced solely to such Joint Venture; (xi) Liens incurred in the ordinary course of business to secure performance of tenders, bids or contracts entered into in the ordinary course of business, including without limitation any rights of offset or liquidated damages, penalties, or other fees that may be contractually agreed to in conjunction with any tender, bid, or contract entered into by us or any of our Subsidiaries in the ordinary course of business; (xii) Liens on current assets of us or any of our Subsidiaries securing our Indebtedness or Indebtedness of any such Subsidiary, respectively; (xiii) deposits made in connection with maintaining self-insurance, to obtain the benefits of laws, regulations or arrangements relating to unemployment insurance, old age pensions, social security or similar matters or to secure surety, appeal or customs bonds; and (xiv) any extensions, substitutions, replacements or renewals in whole or in part of a Lien enumerated in clauses (i) through (xiii) above, provided that the amount of Indebtedness secured by such extension, substitution, replacement or renewal shall not exceed the principal amount of Indebtedness being substituted, extended, replaced or renewed, together with the amount of any premiums, fees, costs and expenses associated with such substitution, extension, replacement or renewal, nor shall the pledge, mortgage or lien be extended to any additional Principal Property unless otherwise permitted under the covenant described under “Limitation on Liens.”
 
Person” means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
 
Principal Property” means any drilling rig or drillship, or integral portion thereof, owned or leased by us or any Subsidiary and used for drilling offshore oil and gas wells, which, in the opinion of the Board of Directors, is of material importance to the business of us and our Subsidiaries taken as a whole, but no such drilling rig or drillship, or portion thereof, shall be deemed of material importance if its net book value (after deducting accumulated depreciation) is less than 2% of Consolidated Net Tangible Assets.
 
Sale/Leaseback Transaction” means any arrangement with any Person pursuant to which we or any Subsidiary leases any Principal Property that has been or is to be sold or transferred by us or the Subsidiary to such Person, other than (1) temporary leases for a term, including renewals at the option of the lessee, of not more than five years; (2) leases between us and a Subsidiary or between Subsidiaries; and (3) leases of Principal Property executed by the time of, or within 12 months after the latest of, the acquisition, the completion of construction, alteration, improvement or repair, or the commencement of commercial operation of the Principal Property.
 
Stated Maturity” when used with respect to any note or any installment of principal thereof or interest thereon, means the date specified in such note as the fixed date on which the principal of such note or such installment of principal or interest is due and payable.
 
Subsidiary” means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.
 
Voting Stock” means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.
  
Wholly Owned Subsidiary” means, with respect to a Person, any Subsidiary of that Person to the extent
 





all of the Voting Stock of such Subsidiary, other than any director’s qualifying shares mandated by applicable law, is owned directly or indirectly by such Person or
such Subsidiary is organized in a foreign jurisdiction and is required by the applicable laws and regulations of such foreign jurisdiction to be partially owned by another Person, if such Person:
directly or indirectly owns the remaining capital stock of such Subsidiary and
by contract or otherwise, controls the management and business of such Subsidiary and derives the economic benefits of ownership of such Subsidiary to substantially the same extent as if such Subsidiary were a Wholly Owned Subsidiary.




Exhibit 4.46

Description of the 5.20% Senior Notes due 2025 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “Definitions” and in other parts of this description.
General
        The notes mature on March 15, 2025 and bear interest at 5.20% per year. We:
pay interest semi-annually on March 15 and September 15 of each year; and
pay interest to the person in whose name a note is registered at the close of business on the March 1 or September 1 preceding the interest payment date.
We compute interest on the basis of a 360-day year consisting of twelve 30-day months, make payments on the notes at the offices of the trustee and any paying agent and may make payments by wire transfer for notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.
        We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
        We may "reopen" the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders.
Optional Redemption
        We may redeem the notes, in whole at any time or in part from time to time, prior to their maturity. If we elect to redeem the notes before the Par Call Date, we will pay a redemption price equal to the greater of:
(1)
100% of the principal amount of the notes to be redeemed; and
(2)
the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the notes matured on the Par Call Date (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below) plus 50 basis points, plus accrued interest thereon to the date of redemption.
        If we elect to redeem the notes on or after the Par Call Date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued interest thereon to the date of redemption.
        Notwithstanding the foregoing, installments of interest on the notes being redeemed that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date according to the notes and the indenture.
        "Comparable Treasury Issue" means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes (assuming, for this purpose, that such notes matured on the Par Call Date) to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
        "Comparable Treasury Price" means, with respect to any redemption date, (i) the average of two Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
        "Par Call Date" means December 15, 2024 (three months prior to the maturity date of such notes).





        "Quotation Agent" means the Reference Treasury Dealer appointed by us.
        "Reference Treasury Dealer" means each of Citigroup Global Markets Inc., Deutsche Bank Securities Inc. and HSBC Securities (USA) Inc. (or their respective affiliates that are Primary Treasury Dealers (as defined below)) and their respective successors and one other nationally recognized investment banking firm that is a primary U.S. Government securities dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), we will substitute therefor another Primary Treasury Dealer.
        "Reference Treasury Dealer Quotations" means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
        "Treasury Rate" means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
        Notice of any redemption described under "Optional Redemption" will be mailed at least three business days (provided that the trustee has received drafts of such notice at least five days in advance thereof, or such shorter period as is satisfactory to the trustee) but in each case not more than 60 days before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by The Depository Trust Company ("DTC"), in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with any applicable procedures of DTC, in the case of notes that are not represented by a global security.
        We may at any time purchase notes on the open market or otherwise at any price. We will surrender all notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
Ranking
        The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
        We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and non-U.S. Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries. As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries' financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
Additional Amounts
        All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, "Taxes") unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for Tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the paying agent or any department or political subdivision thereof or therein (each, a "Tax Jurisdiction") will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts





(the "Additional Amounts") as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; provided, however, that no Additional Amounts will be payable with respect to:
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double Tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable Tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event that any such requirements are imposed as a result of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof) after the Issue Date, this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
any estate, inheritance, gift, transfer, personal property or similar Tax;
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes;
any Taxes required to be withheld pursuant to the EC Council Directive on the Taxation of Savings Income in the Form of Interest Payments (Directive 2003/48/EC) (as amended by EC Counsel Directive 2014/48/EU on March 24, 2014) or any law implementing or complying with, or introduced in order to conform to, such Directive or any agreement between the European Union and any non-EU jurisdiction providing for equivalent measures;
any Taxes required to be withheld in respect of a payment of interest in respect of notes presented for payment by or on behalf of a holder who would be able to avoid such withholding or deduction by presenting the relevant note to another paying agent in a member state of the European Union; or
any combination of the above items.
        We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
        In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to Tax and other liabilities related thereto) which are levied by any Tax Jurisdiction on the execution, delivery, issuance, or registration of any of the notes, the indenture or any other document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
        If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary





to enable the paying agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.
        We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
        Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the paying agent of Additional Amounts, if applicable.
        The obligations under this section will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business for Tax purposes or any jurisdiction from or through which such Person or its paying agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.
Redemption for Changes in Taxes
        We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days' prior written notice to the trustee and the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
(3)
any amendment to, or change in, the laws, Tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after March 4, 2015 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after March 4, 2015, such later date); or
(4)
any amendment to, or change in, an official interpretation or application regarding such laws, Tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective after March 4, 2015 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after March 4, 2015, such later date).
        We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
Events of Default
        An "Event of Default" on the notes occurs if:
1.
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;
2.
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;
3.
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or
4.
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us, and the order or decree remains unstayed and in effect for 60 days.





        The term "Bankruptcy Law" means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term "Custodian" means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
        If any Event of Default (other than an Event of Default specified in clause (3) or (4) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (3) or (4) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice.
        Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (provided, however, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
Modification and Waiver
        We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:
reduce the principal amount of the outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);
make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.
        We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:
to cure any ambiguity, defect or inconsistency;
to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture;
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such





amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof; and
to add a guarantor of the notes.
        The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to those notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
Defeasance and Discharge
        Defeasance.    When we use the term "defeasance," we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:
we will be discharged from our obligations with respect to notes ("legal defeasance"); or
we will no longer have any obligation to comply with any restrictive covenants with respect to the notes and the related Events of Default will no longer apply ("covenant defeasance").
        If the notes are defeased, the holders of the notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.
        We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the U.S. Internal Revenue Service or a change in law to that effect.
        Satisfaction and Discharge.    In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:
either
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and we, in the case of the three preceding bullets, have deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of





notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to such notes have been complied with.
The Trustee
        Deutsche Bank Trust Company Americas is the trustee under the indenture. Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
        The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.
Payment; Paying Agents and Transfer Agents
The trustee has been appointed as paying agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any paying agent. At our option, however, payments may be made by wire transfer for notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.
If the principal of or any premium or interest on notes is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease.
Definitions
        "Bankruptcy Act" means the Bankruptcy Act or Title 11 of the United States Code, as amended.
        "Board of Directors" means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of our Board of Directors or comparable governing body.
        "Capitalized Lease Obligation" of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
        "Default" means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
        "Entity" means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
        "GAAP" means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
        "Indebtedness" means:
all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn





or, to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person's legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.
        "Issue Date" means March 12, 2015, the date on which the notes were first authenticated and delivered under the indenture.
        "Joint Venture" means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Lien" means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
        "Maturity" when used with respect to any notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
        "Officers" means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
        "Officers' Certificate" means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
        "Person" means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
        "Stated Maturity" when used with respect to any note or any installment of principal thereof or interest thereon, means the date specified in such note as the fixed date on which the principal of such note or such installment of principal or interest is due and payable.
        "Subsidiary" means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Voting Stock" means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.




Exhibit 4.47

Description of the 7.75% Senior Notes due 2026 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc, and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “Definitions” and in other parts of this description.
General
        The notes mature on February 1, 2026 and bear interest at 7.75% per year. We:
pay interest semi-annually on February 1 and August 1 of each year;
pay interest to the person in whose name a note is registered at the close of business on the January 15 or July 15 preceding the interest payment date;
compute interest on the basis of a 360-day year consisting of twelve 30-day months;
make payments on the notes at the offices of the trustee and any paying agent; and
may make payments by wire transfer for the notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.
        We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
        We may "reopen" the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders, provided that such additional notes will not have the same CUSIP, ISIN or other identifying numbers as the outstanding notes unless such additional notes are fungible with the outstanding notes for U.S. federal income tax purposes.
Optional Redemption
        We may redeem the notes, in whole at any time or in part from time to time, prior to their maturity. If we elect to redeem the notes before the Par Call Date, we will pay a redemption price equal to the greater of:
(1)
100% of the principal amount of the notes to be redeemed; and
(2)
the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the notes matured on the Par Call Date (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below) plus 50 basis points, plus accrued interest thereon to the date of redemption.
        If we elect to redeem the notes on or after the Par Call Date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued interest thereon to the date of redemption.
        Notwithstanding the foregoing, installments of interest on the notes being redeemed that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date of the notes and the indenture.
        "Comparable Treasury Issue" means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes (assuming, for this purpose, that such notes matured on the Par Call Date) to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
        "Comparable Treasury Price" means, with respect to any redemption date, (i) the average of two Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.





        "Par Call Date" means November 1, 2025 (three months prior to the maturity date of the notes).
        "Quotation Agent" means the Reference Treasury Dealer appointed by us.
        "Reference Treasury Dealer" means each of Deutsche Bank Securities Inc. and Citigroup Global Markets Inc. (or their respective affiliates that are Primary Treasury Dealers (as defined below)) and their respective successors and two other nationally recognized investment banking firms that are Primary Treasury Dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), we will substitute therefor another Primary Treasury Dealer.
        "Reference Treasury Dealer Quotations" means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
        "Treasury Rate" means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
        Notice of any redemption described under "Optional Redemption" will be mailed at least 15 days, but not more than 60 days, before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by DTC, in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with any applicable procedures of DTC, in the case of notes that are not represented by a global security.
        We may at any time purchase notes on the open market or otherwise at any price. We will surrender all notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
Change of Control Offer
        If a Change of Control Triggering Event occurs, unless we have exercised our option to redeem the notes as described above under "Optional Redemption," we will be required to make an offer (the "change of control offer") to each holder of notes to repurchase all or any part of that holder's notes on the terms set forth in the notes. In the change of control offer, we will be required to offer payment in cash equal to 101% of the principal amount of the notes to be repurchased, plus accrued and unpaid interest, if any, on those notes to the repurchase date (the "change of control payment"), subject to the rights of holders of the notes on a regular record date to receive interest due on the related interest payment date falling on or prior to the repurchase date.
        Within 30 days following any Change of Control Triggering Event or, at our option, prior to any Change of Control, but after public announcement of the transaction that constitutes or may constitute the Change of Control, we will mail a notice to holders of the notes, with a copy to the trustee, describing the transaction that constitutes or may constitute the Change of Control Triggering Event and offering to repurchase the notes on the date specified in the notice, which date will be no earlier than 30 days and no later than 60 days from the date such notice is mailed (the "change of control payment date"). The notice, if mailed prior to the date of consummation of the Change of Control, will state that the offer to purchase is conditioned on the Change of Control Triggering Event occurring on or prior to the change of control payment date. In the event that such offer to purchase fails to satisfy the condition in the preceding sentence, we will cause another notice meeting the aforementioned requirements to be mailed to holders of the notes.
        On the change of control payment date, we will, to the extent lawful:
accept for payment all notes or portions of notes properly tendered pursuant to the change of control offer;
deposit with the paying agent an amount equal to the change of control payment in respect of all notes or portions of notes properly tendered; and
deliver or cause to be delivered to the trustee the notes properly accepted together with an officers' certificate stating the aggregate principal amount of notes or portions of notes being repurchased.
        The paying agent will promptly transmit to each holder of properly tendered notes the change of control payment for the notes being repurchased, and the trustee will promptly authenticate and mail (or cause to be transferred by book-entry) to each holder a new note equal in principal amount to any unrepurchased portion, if any, of any notes





surrendered, provided that each new note will be in a principal amount of $2,000 or an integral multiple of $1,000 in excess thereof.
        We will not be required to make a change of control offer upon the occurrence of a Change of Control Triggering Event if a third party makes such an offer in the manner, at the times and otherwise in compliance with the requirements for an offer made by us and the third party repurchases all notes properly tendered and not withdrawn under its offer. In addition, we will not repurchase any notes if there has occurred and is continuing on the change of control payment date an event of default under the indenture, other than a default in the payment of the change of control payment upon a Change of Control Triggering Event.
        Upon the occurrence of a Change of Control Triggering Event, we may not have sufficient funds to repurchase the notes in the amount of the change of control payment in cash at such time. In addition, our ability to repurchase the notes for cash may be limited by law or the terms of other agreements relating to our indebtedness outstanding at the time. The failure to make such repurchase would result in a default under the notes.
        We will comply with the requirements of Rule 14e-1 under the Exchange Act, and any other securities laws and regulations thereunder to the extent those laws and regulations are applicable in connection with the repurchase of the notes as a result of a Change of Control Triggering Event. To the extent that the provisions of any such securities laws or regulations conflict with the change of control offer provisions of the notes, we will comply with those securities laws and regulations and will not be deemed to have breached our obligations under the change of control offer provisions of the notes by virtue of any such conflict.
Ranking
        The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
        We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and non-U.S. Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries. As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries' financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
Additional Amounts
        All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, "Taxes") unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for Tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the paying agent or any department or political subdivision thereof or therein (each, a "Tax Jurisdiction") will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts (the "Additional Amounts") as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; provided, however, that no Additional Amounts will be payable with respect to:
(3)
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);





(4)
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double Tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable Tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event that any such requirements are imposed as a result of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof) after the Issue Date, this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
(5)
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
(6)
any estate, inheritance, gift, transfer, personal property or similar Tax;
(7)
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes; or
(8)
any combination of the above items.
        We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
        In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, stamp duty, stamp duty reserve tax, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to Tax and other liabilities related thereto) which are levied by any Tax Jurisdiction on the execution, delivery, issuance, or registration of any of the notes, the indenture or any other document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
        If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary to enable the paying agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.
        We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
        Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the paying agent of Additional Amounts, if applicable.
        The obligations under this section will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business





for Tax purposes or any jurisdiction from or through which such Person or its paying agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.
Redemption for Changes in Taxes
        We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days' prior written notice to the trustee and the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
(9)
any amendment to, or change in, the laws, Tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after January 11, 2018 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after January 11, 2018, such later date); or
(10)
any amendment to, or change in, an official interpretation or application regarding such laws, Tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective January 11, 2018 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after January 11, 2018, such later date).
        We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
Restrictive Covenants
Limitation on Liens
        We will not, and will not permit any of our Subsidiaries to, incur, issue or assume any Indebtedness for borrowed money secured by any Lien upon any Principal Property or any shares of stock or Indebtedness of any Subsidiary that owns or leases a Principal Property (whether such Principal Property, shares of stock or Indebtedness are now owned or hereafter acquired) without making effective provision whereby the notes (together with, if we so determine, any other Indebtedness or other obligation of us or any Subsidiary) shall be secured equally and ratably with (or, at our option, prior to) the Indebtedness so secured by a Lien on the same assets of us or such Subsidiary, as the case may be, for so long as such Indebtedness is so secured. The foregoing restrictions will not, however, apply to Indebtedness secured by Permitted Liens.
        Notwithstanding the foregoing, we and our Subsidiaries may, without securing the notes, incur, issue or assume Indebtedness that would otherwise be subject to the foregoing restrictions in an aggregate principal amount that, together with all other such Indebtedness of us and our Subsidiaries that would otherwise be subject to the foregoing restrictions (not including Indebtedness permitted to be secured under the definition of Permitted Liens) and the aggregate amount of Attributable Indebtedness deemed outstanding with respect to Sale/Leaseback Transactions (other than Sale/ Leaseback Transactions in connection with which we have voluntarily retired any of the notes, any Pari Passu Indebtedness or any Funded Indebtedness pursuant to clause (i) of the third bullet below under "Limitation on Sale Leaseback Transactions") does not at any one time exceed 15% of Consolidated Net Tangible Assets.
        For purposes of this covenant, if at the time any Indebtedness is incurred, issued or assumed, such Indebtedness is unsecured but is later secured by a Lien, such Indebtedness shall be deemed to be incurred at the time that such Indebtedness is so secured by a Lien.
Limitation on Sale/Leaseback Transactions
        So long as the notes are outstanding, we will not, and we will not permit any Subsidiary to, sell or transfer (other than to us or a Wholly Owned Subsidiary) any Principal Property, whether owned at the date of the indenture or thereafter acquired, which has been in full operation for more than 120 days prior to such sale or transfer, with the intention of entering into a lease of such Principal Property (except for a lease for a term, including any renewal thereof, of not more than three years), if after giving effect thereto the Attributable Indebtedness in respect of all such sale and leaseback transactions involving Principal Properties shall be in excess of 15% of Consolidated Net Tangible Assets.





        Notwithstanding the foregoing, we or any Subsidiary may sell any Principal Property and lease it back if the net proceeds of such sale are at least equal to the fair value of such property as determined by our Board of Directors and:
we or such Subsidiary would be entitled to incur Indebtedness in a principal amount equal to the Attributable Indebtedness with respect to such Sale/Leaseback Transaction secured by a Lien on the property subject to such Sale/Leaseback Transaction pursuant to the covenant described under "Limitation on Liens" above without equally and ratably securing the notes pursuant to such covenant;
after the Issue Date and within a period commencing nine months prior to the consummation of such Sale/Leaseback Transaction and ending nine months after the consummation thereof, we or such Subsidiary shall have expended for property used or to be used in the ordinary course of our business and that of our Subsidiaries an amount equal to all or a portion of the net proceeds of such Sale/Leaseback Transaction and we shall have elected to designate such amount as a credit against such Sale/Leaseback Transaction (with any such amount not being so designated to be applied as set forth in the following bullet or as otherwise permitted); or
we, during the nine-month period after the effective date of such Sale/Leaseback Transaction, shall have applied to either (i) the voluntary defeasance or retirement of any notes, any Pari Passu Indebtedness or any Funded Indebtedness or (ii) the acquisition of one or more Principal Properties at fair value, an amount equal to the greater of the net proceeds of the sale or transfer of the property leased in such Sale/Leaseback Transaction and the fair value, as determined by our Board of Directors, of such property as of the time of entering into such Sale/Leaseback Transaction (in either case adjusted to reflect the remaining term of the lease and any amount expended by us as set forth in the preceding bullet), less an amount equal to the sum of the principal amount of notes, Pari Passu Indebtedness and Funded Indebtedness voluntarily defeased or retired by us plus any amount expended to acquire any Principal Properties at fair value, within such nine month period and not designated as a credit against any other Sale/Leaseback Transaction entered into by us or any of our Subsidiaries during such period.
Consolidation, Merger and Sale of Assets
        We will not, directly or indirectly, in any transaction or series of related transactions: (1) consolidate or merge with or into another Person (whether or not we are the surviving Person); (2) sell, assign, transfer, convey or otherwise dispose of all or substantially all of our and our Subsidiaries' properties or assets taken as a whole, or (3) assign any of our obligations under the notes and the indenture, in one or more related transactions, to another Person; unless:
either: (A) we are the surviving or continuing Person; or (B) the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made is an Entity, validly organized and existing in good standing (to the extent the concept of good standing is applicable) under the laws of any state of the United States, the District of Columbia, the Cayman Islands, Bermuda, Switzerland, the United Kingdom, the Kingdom of the Netherlands, the Grand Duchy of Luxembourg, Ireland, or any other member country of the European Union;
the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made assumes all our obligations under the notes and the indenture;
immediately after such transaction no Default or Event of Default exists; and
we shall have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that such merger, consolidation, amalgamation or sale, assignment, transfer, conveyance or other disposition of such properties or assets or assignment of our obligations under the notes and the indenture and such supplemental indenture, if any, comply with the indenture.
        We will not, directly or indirectly, lease all or substantially all of our properties or assets, in one or more related transactions, to any other Person.
        Notwithstanding the foregoing, the limitations described above shall not apply to a sale, assignment, transfer, conveyance or other disposition of assets between or among us and any of our Wholly Owned Subsidiaries.
Events of Default
        An "Event of Default" on the notes occurs if:





1.
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;
2.
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;
3.
we fail to comply with any of our other agreements in the notes or the indenture (as they relate thereto), which shall not have been remedied within the specified period after written notice, as specified below;
4.
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or
5.
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us,
and the order or decree remains unstayed and in effect for 60 days.
        The term "Bankruptcy Law" means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term "Custodian" means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
        If any Event of Default (other than an Event of Default specified in clause (4) or (5) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (4) or (5) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice.
        Notwithstanding the foregoing, a Default under clause (3) above is not an Event of Default until the trustee notifies us, or the holders of at least 25% in principal amount of the then outstanding notes notify us and the trustee, of the Default, and we fail to cure the Default within 90 days after receipt of the notice. The notice must specify the Default, demand that it be remedied and state that the notice is a "Notice of Default."
        Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (provided, however, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration, with respect to the notes). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
Modification and Waiver
        We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:
reduce the principal amount of the then outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of notes of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);





make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.
        We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:
to cure any ambiguity, defect or inconsistency;
to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture described under "Consolidation, Merger and Sale of Assets";
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof;
to add a guarantor of the notes; and
to conform any provision to the "Description of Notes" section of the prospectus supplement dated January 11, 2018 related to the offering of the notes.
        The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to such notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
Defeasance and Discharge
        Defeasance.    When we use the term "defeasance," we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:
we will be discharged from our obligations with respect to the notes ("legal defeasance"); or
we will no longer have any obligation to comply with specified restrictive covenants with respect to the notes, the covenant described under "-Consolidation, Merger and Sales of Assets" and other specified covenants under the indenture, and the related Events of Default will no longer apply ("covenant defeasance").
        If the notes are defeased, the holders of the notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.





        We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the U.S. Internal Revenue Service or a change in law to that effect.
        Satisfaction and Discharge.    In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:
either:
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and we, in the case of the three preceding bullets, have deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to the notes have been complied with.

The Trustee
        Deutsche Bank Trust Company Americas is the trustee under the indenture. Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
        The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.
Payment; Paying Agents and Transfer Agents
The trustee has been appointed as paying agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any paying agent. At our option, however, payments may be made by wire transfer for notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.





If the principal of or any premium or interest on the notes is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease.
Definitions
        "Attributable Indebtedness," when used with respect to any Sale/Leaseback Transaction, means, as at the time of determination, the present value (discounted at the rate set forth or implicit in the terms of the lease included in such transaction) of the total obligations of the lessee for rental payments (other than amounts required to be paid on account of taxes, maintenance, repairs, insurance, assessments, utilities, operating and labor costs and other items which do not constitute payments for property rights) during the remaining term of the lease included in such Sale/Leaseback Transaction (including any period for which such lease has been extended). In the case of any lease which is terminable by the lessee upon the payment of a penalty, such net amount shall be the lesser of the net amount determined assuming termination upon the first date such lease may be terminated (in which case the net amount shall also include the amount of the penalty, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated) or the net amount determined assuming no such termination.
        "Bankruptcy Act" means the Bankruptcy Act or Title 11 of the United States Code, as amended.
        "Board of Directors" means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of our Board of Directors or comparable governing body.
        "Capitalized Lease Obligation" of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
        "Change of Control" means the occurrence of any of the following: (1) the consummation of any transaction (including, without limitation, any merger or consolidation) the result of which is that any "person" (as that term is used in Section 13(d)(3) of the Exchange Act) (other than Ensco, any subsidiary or employee benefit plan of Ensco or employee benefit plan of any subsidiary of Ensco) becomes the beneficial owner (as defined in Rules 13d-3 and 13d-5 under the Exchange Act), directly or indirectly, of more than 50% of the voting stock of Ensco or other voting stock into which the voting stock of Ensco is reclassified, consolidated, exchanged or changed, measured by voting power rather than number of shares; or (2) the direct or indirect sale, transfer, conveyance or other disposition (other than by way of merger or consolidation), in one or more series of transactions approved by the board of directors of Ensco as part of a single plan, of all or substantially all of the assets of Ensco as shown on Ensco's most recent audited balance sheet, to one or more "persons" (as that term is defined in the indenture) (other than Ensco or one of the subsidiaries of Ensco). Notwithstanding the foregoing, a transaction will not be deemed to involve a change of control if (1) Ensco becomes a direct or indirect wholly-owned subsidiary of a Person and (2)(A) the direct or indirect holders of the voting stock of such Person immediately following that transaction are substantially the same as the holders of the voting stock of Ensco immediately prior to that transaction or (B) immediately following that transaction, no person or group (other than a Person satisfying the requirements of this sentence) is the beneficial owner, directly or indirectly, of more than 50% of the voting stock of such Person.
        "Change of Control Triggering Event" means the occurrence of a Change of Control, which occurrence is followed by a Rating Decline within 90 days thereof.
        "Consolidated Net Tangible Assets" means the total amount of assets (after deducting applicable reserves and other properly deductible items) less:
all current liabilities (excluding liabilities that are extendible or renewable at our option to a date more than 12 months after the date of calculation and excluding current maturities of long-term Indebtedness); and
all goodwill, trade names, trademarks, patents, unamortized debt discount and expense and other like intangible assets.





We will calculate our Consolidated Net Tangible Assets based on our most recent quarterly balance sheet and in accordance with GAAP.
        "Default" means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
        "Entity" means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
        "Funded Indebtedness" means all Indebtedness that matures on or is renewable to a date more than one year after the date the Indebtedness is incurred.
        "GAAP" means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
        "Indebtedness" means:
all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn or, to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person's legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.
        "Issue Date" means January 26, 2018, the date on which the notes were first authenticated and delivered under the indenture.
        "Joint Venture" means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Lien" means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
        "Maturity" when used with respect to the notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
        "Moody's" means Moody's Investors Service, Inc., and its successors.
        "Officers" means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
        "Officers' Certificate" means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
        "Pari Passu Indebtedness" means any of our Indebtedness, whether outstanding on the Issue Date or thereafter created, incurred or assumed, unless, in the case of any particular Indebtedness, the instrument creating or evidencing the same or pursuant to which the same is outstanding expressly provides that such Indebtedness shall be subordinated in right of payment to the notes.
        "Permitted Liens" shall mean (i) Liens existing on the Issue Date; (ii) Liens on property or assets of, or any shares of stock of, or other equity interests in, or Indebtedness of, any Person existing at the time such Person becomes a





Subsidiary of us or at the time such Person is merged into or consolidated with us or any of our Subsidiaries or at the time of a sale, lease or other disposition of the properties of a Person (or a division thereof) as an entirety or substantially as an entirety to us or a Subsidiary, and not incurred in contemplation of such merger, consolidation, sale, lease or other disposition; (iii) Liens in favor of us or any of our Subsidiaries or Liens securing debt of a Subsidiary owing to us or to another Subsidiary; (iv) Liens in favor of governmental bodies to secure partial, progress, advance or other payments or performance pursuant to the provisions of any contract or statute; (v) Liens securing industrial revenue, pollution control or similar revenue bonds; (vi) Liens on assets existing at the time of acquisition thereof, securing all or any portion of the cost of acquiring, constructing, improving, developing, expanding or repairing such assets or securing Indebtedness incurred prior to, at the time of, or within 24 months after, the later of the acquisition, the completion of construction, improvement, development, expansion or repair or the commencement of commercial operation of such assets, for the purpose of (a) financing all or any part of the purchase price of such assets or (b) financing all or any part of the cost of construction, improvement, development, expansion or repair of any such assets; (vii) statutory liens or landlords', carriers', warehouseman's, mechanics', suppliers', materialmen's, repairmen's, maritime or other like Liens arising in the ordinary course of business and with respect to amounts not yet delinquent or being contested in good faith by appropriate proceedings; (viii) Liens in connection with in rem and other legal proceedings, which are being contested in good faith; (ix) Liens securing taxes, assessments, government charges or levies not yet due or delinquent, or which can thereafter be paid without penalty, or which are being contested in good faith by appropriate proceedings; (x) Liens on the stock, partnership or other equity interest of us or any Subsidiary in any Joint Venture or any Subsidiary that owns an equity interest in such Joint Venture to secure Indebtedness, provided the amount of such Indebtedness is contributed and/or advanced solely to such Joint Venture; (xi) Liens incurred in the ordinary course of business to secure performance of tenders, bids or contracts entered into in the ordinary course of business, including without limitation any rights of offset or liquidated damages, penalties, or other fees that may be contractually agreed to in conjunction with any tender, bid, or contract entered into by us or any of our Subsidiaries in the ordinary course of business; (xii) Liens on current assets of us or any of our Subsidiaries securing our Indebtedness or Indebtedness of any such Subsidiary, respectively; (xiii) deposits made in connection with maintaining self-insurance, to obtain the benefits of laws, regulations or arrangements relating to unemployment insurance, old age pensions, social security or similar matters or to secure surety, appeal or customs bonds; and (xiv) any extensions, substitutions, replacements or renewals in whole or in part of a Lien enumerated in clauses (i) through (xiii) above, provided that the amount of Indebtedness secured by such extension, substitution, replacement or renewal shall not exceed the principal amount of Indebtedness being substituted, extended, replaced or renewed, together with the amount of any premiums, fees, costs and expenses associated with such substitution, extension, replacement or renewal, nor shall the pledge, mortgage or lien be extended to any additional Principal Property unless otherwise permitted under the covenant described under "Limitation on Liens."
        "Person" means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
        "Principal Property" means any drilling rig or drillship, or integral portion thereof, owned or leased by us or any Subsidiary and used for drilling offshore oil and gas wells, which, in the opinion of the Board of Directors, is of material importance to the business of us and our Subsidiaries taken as a whole, but no such drilling rig or drillship, or portion thereof, shall be deemed of material importance if its net book value (after deducting accumulated depreciation) is less than 2% of Consolidated Net Tangible Assets.
        "Rating Category" means:
with respect to S&P, any of the following categories: AAA, AA, A, BBB, BB, B, CCC, CC, C and D (or equivalent successor categories); and
with respect to Moody's, any of the following categories: Aaa, Aa, A, Baa, Ba, B, Caa, Ca, C and D (or equivalent successor categories).
        "Rating Decline" means a decrease in the rating of the notes by both Moody's and S&P by one or more gradations (including gradations within Rating Categories as well as between Rating Categories). In determining whether the rating of the notes has decreased by one or more gradations, gradations within Rating Categories, namely + or - for S&P, and 1, 2, and 3 for Moody's, will be taken into account; for example, in the case of S&P, a rating decline either from BB+ to BB or BB- to B+ will constitute a decrease of one gradation.





        "S&P" means S&P Global Ratings, a division of S&P Global Inc., and its successors.
        "Sale/Leaseback Transaction" means any arrangement with any Person pursuant to which we or any Subsidiary leases any Principal Property that has been or is to be sold or transferred by us or the Subsidiary to such Person, other than (1) temporary leases for a term, including renewals at the option of the lessee, of not more than five years; (2) leases between us and a Subsidiary or between Subsidiaries; and (3) leases of Principal Property executed by the time of, or within 12 months after the latest of, the acquisition, the completion of construction, alteration, improvement or repair, or the commencement of commercial operation of the Principal Property.
        "Stated Maturity" when used with respect to the notes or any installment of principal thereof or interest thereon, means the date specified as the fixed date on which the principal of the notes or such installment of principal or interest is due and payable.
        "Subsidiary" means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Voting Stock" means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.
        "Wholly Owned Subsidiary" means, with respect to a Person, any Subsidiary of that Person to the extent
all of the Voting Stock of such Subsidiary, other than any director's qualifying shares mandated by applicable law, is owned directly or indirectly by such Person or
such Subsidiary is organized in a foreign jurisdiction and is required by the applicable laws and regulations of such foreign jurisdiction to be partially owned by another Person, if such Person:
directly or indirectly owns the remaining capital stock of such Subsidiary and
by contract or otherwise, controls the management and business of such Subsidiary and derives the economic benefits of ownership of such Subsidiary to substantially the same extent as if such Subsidiary were a Wholly Owned Subsidiary.




Exhibit 4.48

Description of the 5.75% Senior Notes due 2044 (the “notes”),
Registered Under Section 12 of the Securities Exchange Act of 1934

The following summary of Valaris plc’s (the “Company”) above referenced notes is based on and qualified by the Indenture, dated as of March 17, 2011, between the Company and Deutsche Bank Trust Company Americas, as trustee (the “trustee”), as supplemented with applicability to the notes (the “indenture”). For a complete description of the terms and provisions of the notes, refer to the indenture and the form of notes, which are filed as exhibits to this Annual Report on Form 10-K. Throughout this exhibit, references to “we,” “our,” and “us” refer to Valaris plc and not to any of its subsidiaries. In addition, we have used in this description capitalized and other terms that we have defined below under “Definitions” and in other parts of this description.
General
        The notes mature on October 1, 2044 and bear interest at 5.75% per year. We:
pay interest semi-annually on April 1 and October 1 of each year; and
pay interest to the person in whose name a note is registered at the close of business on the March 15 or September 15 preceding the interest payment date.
        We compute interest on the basis of a 360-day year consisting of twelve 30-day months, make payments on the notes at the offices of the trustee and any paying agent and may make payments by wire transfer for notes held in book-entry form or by check mailed to the address of the person entitled to the payment as it appears in the note register.
        We issued the notes in fully registered form, without coupons, in minimum denominations of $2,000 and any integral multiples of $1,000 above that amount.
        We may "reopen" the notes and issue an unlimited principal amount of additional notes in the future without the consent of the holders.
Optional Redemption
        We may redeem the notes, in whole at any time or in part from time to time, prior to their maturity. If we elect to redeem the notes before the Par Call Date, we will pay a redemption price equal to the greater of:
(1)
100% of the principal amount of the notes to be redeemed; and
(2)
the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the notes matured on the Par Call Date (not including any portion of such payments of interest accrued as of the date of redemption), discounted to the date of redemption on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate (as defined below) plus 40 basis points, plus accrued interest thereon to the date of redemption.
        If we elect to redeem the notes on or after the Par Call Date, we will pay an amount equal to 100% of the principal amount of the notes redeemed plus accrued interest thereon to the date of redemption.
        Notwithstanding the foregoing, installments of interest on the notes being redeemed that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date according to the notes and the indenture.
        "Comparable Treasury Issue" means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the notes (assuming, for this purpose, that such notes matured on the Par Call Date) to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such notes.
        "Comparable Treasury Price" means, with respect to any redemption date, (i) the average of two Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if we are given fewer than four such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
        "Par Call Date" means April 1, 2044 (six months prior to the maturity date of such notes).





        "Quotation Agent" means the Reference Treasury Dealer appointed by us.
        "Reference Treasury Dealer" means Citigroup Global Markets Inc. and Deutsche Bank Securities Inc. (or their respective affiliates that are Primary Treasury Dealers (as defined below)), and their respective successors and two other nationally recognized investment banking firms that are primary U.S. Government securities dealers specified from time to time by us; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), we will substitute therefor another Primary Treasury Dealer.
        "Reference Treasury Dealer Quotations" means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by us, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to us by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third business day preceding such redemption date.
        "Treasury Rate" means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
        Notice of any redemption described under "Optional Redemption" will be mailed at least 30 days but not more than 60 days before the redemption date to each holder (with a copy to the trustee) of the notes to be redeemed. Unless we default in payment of the redemption price, on and after the redemption date, interest will cease to accrue on the notes or portions thereof called for redemption. If less than all of the notes are to be redeemed, the notes to be redeemed shall be selected by lot by The Depository Trust Company ("DTC"), in the case of notes represented by a global security, or by the trustee by a method the trustee deems to be fair and appropriate and in accordance with any applicable procedures of DTC, in the case of notes that are not represented by a global security.
        We may at any time purchase notes on the open market or otherwise at any price. We will surrender all notes that we redeem or purchase to the trustee for cancellation. We may not reissue or resell any of these notes.
Ranking
        The notes constitute our senior unsecured debt and rank equally in right of payment with our senior unsecured debt from time to time outstanding and senior in right of payment to any future subordinated debt from time to time outstanding. The notes are effectively junior to our secured debt from time to time outstanding to the extent of the value of the assets securing that debt.
        We are a holding company and do not conduct any business operations or have any significant assets other than interests in our Subsidiaries. We currently conduct our operations through both U.S. and non-U.S. Subsidiaries, and our operating income and cash flow are generated by our Subsidiaries. As a result, cash we obtain from our Subsidiaries is the principal source of funds necessary to meet our debt service obligations. Contractual provisions or laws, as well as our Subsidiaries' financial condition and operating requirements, may limit our ability to obtain cash from our Subsidiaries that we require to pay our debt service obligations, including payments on the notes. The notes are obligations solely of us and are not guaranteed by any of our Subsidiaries. Therefore, holders of the notes have a junior position to the claims of creditors, including trade creditors and tort claimants, of our Subsidiaries with respect to their assets and earnings.
Additional Amounts
        All payments made under or with respect to the notes will be made free and clear of and without withholding or deduction for, or on account of, any present or future tax, duty, levy, impost, assessment or other governmental charge (including penalties, interest, additions to tax and other liabilities related thereto) (collectively, "Taxes") unless the withholding or deduction of such Taxes is then required by law. If any deduction or withholding for, or on account of, any Taxes imposed or levied by or on behalf of (1) any jurisdiction in which we are organized, resident or doing business for Tax purposes or any department or political subdivision thereof or therein or (2) any jurisdiction from or through which payment is made by us or the paying agent or any department or political subdivision thereof or therein (each, a "Tax Jurisdiction") will at any time be required to be made from any payments made under or with respect to the notes, including payments of principal, redemption price, interest or premium, we will pay such additional amounts (the "Additional Amounts") as may be necessary in order that the net amounts received in respect of such payments by each holder after such withholding or deduction (including any such deduction or withholding in respect of Additional





Amounts) will equal the respective amounts which would have been received in respect of such payments in the absence of such withholding or deduction; provided, however, that no Additional Amounts will be payable with respect to:
any Taxes, to the extent such Taxes would not have been imposed but for the existence of any present or former connection between the holder or the beneficial owner of the notes and the relevant Tax Jurisdiction (other than any connection arising solely from the acquisition, ownership, holding or disposition of the notes, the enforcement of rights under the notes and/or the receipt of any payments in respect of the notes);
any Taxes, to the extent such Taxes would not have been imposed but for the failure of the holder or the beneficial owner of the notes to comply with any certification, identification, information, documentation, or other reporting requirements, including an application for relief under an applicable double Tax treaty, whether required by statute, treaty, regulation or administrative practice of a Tax Jurisdiction, as a precondition to exemption from, or reduction in the rate of deduction or withholding of, Taxes imposed by the Tax Jurisdiction (including, without limitation, a certification that the holder or beneficial owner is not resident in the Tax Jurisdiction or is a resident of an applicable Tax treaty jurisdiction), but in each case, only to the extent the holder or the beneficial owner is legally eligible to provide such certification or documentation; provided, however, that in the event that any such requirements are imposed as a result of an amendment to, or change in, any laws, Tax treaties, regulations or rulings (or any official administrative or judicial interpretation thereof) after the Issue Date, this paragraph (2) will apply only if we notify the trustee, at least 30 days before any such withholding or deduction would be payable, that holders or beneficial owners must comply with such certification, identification, information, documentation or other reporting requirements;
any Taxes, to the extent such Taxes were imposed as a result of the presentation of a note for payment (where presentation is required) more than 30 days after the relevant payment is first made available for payment to the holder (except to the extent that the holder would have been entitled to Additional Amounts had the note been presented on the last day of such 30 day period);
any estate, inheritance, gift, transfer, personal property or similar Tax;
any Taxes payable otherwise than by deduction or withholding from payments made under or with respect to the notes;
any Taxes required to be withheld pursuant to the EC Council Directive on the Taxation of Savings Income in the Form of Interest Payments (Directive 2003/48/EC) (as amended by EC Counsel Directive 2014/48/EU on March 24, 2014) or any law implementing or complying with, or introduced in order to conform to, such Directive or any agreement between the European Union and any non-EU jurisdiction providing for equivalent measures;
any Taxes required to be withheld in respect of a payment of interest in respect of notes presented for payment by or on behalf of a holder who would be able to avoid such withholding or deduction by presenting the relevant note to another paying agent in a member state of the European Union; or
any combination of the above items.
        We also will not pay any Additional Amounts to any holder who is a fiduciary or partnership or other than the sole beneficial owner of the note to the extent that the obligation to pay Additional Amounts would be reduced or eliminated by transferring the notes in question to the sole beneficial owner, but only if there is no material commercial or legal impediment to, or material cost associated with, transferring the notes to the sole beneficial owner.
        In addition to the foregoing, we will also pay and indemnify the holder for any present or future stamp, issue, registration, transfer, court or documentary taxes, or any other excise or property taxes, charges or similar levies (including penalties, interest, additions to Tax and other liabilities related thereto) which are levied by any Tax Jurisdiction on the execution, delivery, issuance, or registration of any of the notes, the indenture or any other document or instrument referred to therein, or the receipt of any payments with respect to, or enforcement of, the notes.
        If we become aware that we will be obligated to pay Additional Amounts with respect to any payment under or with respect to the notes, we will deliver to the trustee on a date which is at least 30 days prior to the date of that payment (unless the obligation to pay Additional Amounts arises after the 30th day prior to that payment date, in which case we shall notify the trustee promptly thereafter) notice stating the fact that Additional Amounts will be payable and the amount estimated to be so payable. The notice must also set forth any other information reasonably necessary to enable the paying agent to pay Additional Amounts to holders on the relevant payment date. We will provide the trustee with documentation reasonably satisfactory to the trustee evidencing the payment of Additional Amounts.





        We will timely make all withholdings and deductions required by law and will remit the full amount deducted or withheld to the relevant Tax authority in accordance with applicable law. We will furnish to the trustee (or to a holder upon request), within a reasonable time after the date the payment of any Taxes so deducted or withheld is made, certified copies of Tax receipts evidencing payment by us, or if receipts are not reasonably available, other evidence of payment reasonably satisfactory to the trustee.
        Whenever in the indenture or in this description of notes there is mentioned, in any context, the payment of amounts based upon the principal amount of the notes or of principal, interest or of any other amount payable under, or with respect to, any of the notes such mention shall be deemed to include the payment to the paying agent of Additional Amounts, if applicable.
        The obligations under this section will survive any termination, defeasance or discharge of the indenture and will apply, mutatis mutandis, to any jurisdiction in which any successor Person to us is organized, resident or doing business for Tax purposes or any jurisdiction from or through which such Person or its paying agent makes any payment on the notes and, in each case, any department or political subdivision thereof or therein.
Redemption for Changes in Taxes
        We may redeem the notes, in whole but not in part, at our option upon giving not less than 30 nor more than 60 days' prior written notice to the trustee and the holders, at a redemption price equal to 100% of the aggregate principal amount thereof, together with accrued and unpaid interest, if any, to the redemption date and all Additional Amounts, if any, which otherwise would be payable, if on the next date on which any amount would be payable in respect of the notes, we would be required to pay Additional Amounts, and we cannot avoid any such payment obligation by taking reasonable measures available to us, as a result of:
any amendment to, or change in, the laws, Tax treaties or any regulations or rulings promulgated thereunder of a relevant Tax Jurisdiction which is announced and becomes effective after September 24, 2014 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after September 24, 2014, such later date); or
any amendment to, or change in, an official interpretation or application regarding such laws, Tax treaties, regulations or rulings, including by virtue of a holding, judgment or order by a court of competent jurisdiction which is announced and becomes effective after September 24, 2014 (or, if the applicable Tax Jurisdiction became a Tax Jurisdiction on a date after September 24, 2014, such later date).
        We will not give any such notice of redemption earlier than 90 days prior to the earliest date on which we would be obligated to pay Additional Amounts or more than 365 days after the applicable law change takes effect, and, at the time such notice is given, the obligation to pay Additional Amounts must remain in effect.
Restrictive Covenants
Limitation on Liens
        We will not, and will not permit any of our Subsidiaries to, incur, issue or assume any Indebtedness for borrowed money secured by any Lien upon any Principal Property or any shares of stock or Indebtedness of any Subsidiary that owns or leases a Principal Property (whether such Principal Property, shares of stock or Indebtedness are now owned or hereafter acquired) without making effective provision whereby the notes (together with, if we so determine, any other Indebtedness or other obligation of us or any Subsidiary) shall be secured equally and ratably with (or, at our option, prior to) the Indebtedness so secured by a Lien on the same assets of us or such Subsidiary, as the case may be, for so long as such Indebtedness is so secured. The foregoing restrictions will not, however, apply to Indebtedness secured by Permitted Liens.
        Notwithstanding the foregoing, we and our Subsidiaries may, without securing the notes, incur, issue or assume Indebtedness that would otherwise be subject to the foregoing restrictions in an aggregate principal amount that, together with all other such Indebtedness of us and our Subsidiaries that would otherwise be subject to the foregoing restrictions (not including Indebtedness permitted to be secured under the definition of Permitted Liens) and the aggregate amount of Attributable Indebtedness deemed outstanding with respect to Sale/Leaseback Transactions (other than Sale/ Leaseback Transactions in connection with which we have voluntarily retired any of the notes, any Pari Passu Indebtedness or any Funded Indebtedness pursuant to clause (i) of the third bullet below under "Limitation on Sale/Leaseback Transactions") does not at any one time exceed 15% of Consolidated Net Tangible Assets.





        For purposes of this covenant, if at the time any Indebtedness is incurred, issued or assumed, such Indebtedness is unsecured but is later secured by a Lien, such Indebtedness shall be deemed to be incurred at the time that such Indebtedness is so secured by a Lien.
Limitation on Sale/Leaseback Transactions
        So long as notes are outstanding, we will not, and we will not permit any Subsidiary to, sell or transfer (other than to us or a Wholly Owned Subsidiary) any Principal Property, whether owned at the date of the indenture or thereafter acquired, which has been in full operation for more than 120 days prior to such sale or transfer, with the intention of entering into a lease of such Principal Property (except for a lease for a term, including any renewal thereof, of not more than three years), if after giving effect thereto the Attributable Indebtedness in respect of all such sale and leaseback transactions involving Principal Properties shall be in excess of 15% of Consolidated Net Tangible Assets.
        Notwithstanding the foregoing, we or any Subsidiary may sell any Principal Property and lease it back if the net proceeds of such sale are at least equal to the fair value of such property as determined by our Board of Directors and:
we or such Subsidiary would be entitled to incur Indebtedness in a principal amount equal to the Attributable Indebtedness with respect to such Sale/Leaseback Transaction secured by a Lien on the property subject to such Sale/Leaseback Transaction pursuant to the covenant described under "Limitation on Liens" above without equally and ratably securing the notes pursuant to such covenant;
after the Issue Date and within a period commencing nine months prior to the consummation of such Sale/Leaseback Transaction and ending nine months after the consummation thereof, we or such Subsidiary shall have expended for property used or to be used in the ordinary course of our business and that of our Subsidiaries an amount equal to all or a portion of the net proceeds of such Sale/Leaseback Transaction and we shall have elected to designate such amount as a credit against such Sale/Leaseback Transaction (with any such amount not being so designated to be applied as set forth in the following bullet or as otherwise permitted); or
we, during the nine-month period after the effective date of such Sale/Leaseback Transaction, shall have applied to either (i) the voluntary defeasance or retirement of any notes, any Pari Passu Indebtedness or any Funded Indebtedness or (ii) the acquisition of one or more Principal Properties at fair value, an amount equal to the greater of the net proceeds of the sale or transfer of the property leased in such Sale/Leaseback Transaction and the fair value, as determined by our Board of Directors, of such property as of the time of entering into such Sale/Leaseback Transaction (in either case adjusted to reflect the remaining term of the lease and any amount expended by us as set forth in the preceding bullet), less an amount equal to the sum of the principal amount of notes, Pari Passu Indebtedness and Funded Indebtedness voluntarily defeased or retired by us plus any amount expended to acquire any Principal Properties at fair value, within such nine month period and not designated as a credit against any other Sale/Leaseback Transaction entered into by us or any of our Subsidiaries during such period.
Consolidation, Merger and Sale of Assets
        We will not, directly or indirectly, in any transaction or series of related transactions: (1) consolidate or merge with or into another Person (whether or not we are the surviving Person); (2) sell, assign, transfer, convey or otherwise dispose of all or substantially all of our and our Subsidiaries' properties or assets taken as a whole, or (3) assign any of our obligations under the notes and the indenture, in one or more related transactions, to another Person; unless:
either: (A) we are the surviving or continuing Person; or (B) the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made is an Entity, validly organized and existing in good standing (to the extent the concept of good standing is applicable) under the laws of any state of the United States, the District of Columbia, the Cayman Islands, Bermuda, Switzerland, the United Kingdom, the Kingdom of the Netherlands, the Grand Duchy of Luxembourg, Ireland, or any other member country of the European Union;
the Person formed by, surviving or continued by any such consolidation, amalgamation or merger (if other than us) or the Person to which such sale, assignment, transfer, conveyance or other disposition shall have been made assumes all our obligations under the notes and the indenture;
immediately after such transaction no Default or Event of Default exists; and





we shall have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that such merger, consolidation, amalgamation or sale, assignment, transfer, conveyance or other disposition of such properties or assets or assignment of our obligations under the notes and the indenture and such supplemental indenture, if any, comply with the indenture.
        We will not, directly or indirectly, lease all or substantially all of our properties or assets, in one or more related transactions, to any other Person.
        Notwithstanding the foregoing, the limitations described above shall not apply to a sale, assignment, transfer, conveyance or other disposition of assets between or among us and any of our Wholly Owned Subsidiaries.
Events of Default
        An "Event of Default" on the notes occurs if:
1.
we default in the payment of interest on any note when the same becomes due and payable and the Default continues for a period of 30 days;
2.
we default in the payment of the principal of any note when the same becomes due and payable at maturity, upon redemption or otherwise;
3.
we fail to comply with any of our other agreements in the notes or the indenture (as they relate thereto), which shall not have been remedied within the specified period after written notice, as specified below;
4.
we pursuant to or within the meaning of any Bankruptcy Law shall:
(a)
commence a voluntary case,
(b)
consent to the entry of an order for relief against us in an involuntary case,
(c)
consent to the appointment of a Custodian of us for all or substantially all of the property of us, or
(d)
make a general assignment for the benefit of creditors; or
5.
a court of competent jurisdiction enters into an order or decree under any Bankruptcy Law that:
(a)
is for relief against us in an involuntary case, or
(b)
appoints a Custodian of us or substantially all of the property of us, or
(c)
orders the liquidation of us, and the order or decree remains unstayed and in effect for 60 days.
        The term "Bankruptcy Law" means the Bankruptcy Act or any similar Federal or State law for the relief of debtors. The term "Custodian" means any receiver, trustee, assignee, liquidator or similar official under any Bankruptcy Law.
        If any Event of Default (other than an Event of Default specified in clause (4) or (5) above) with respect to the notes occurs and is continuing, either the trustee or the holders of at least 25% in principal amount of the then outstanding notes may declare all the notes to be due and payable immediately. Upon any such declaration, the notes shall become due and payable immediately, by a notice in writing to us (and to the trustee if given by holders). Notwithstanding the foregoing, if an Event of Default specified in clause (4) or (5) above hereof occurs with respect to us, all outstanding notes shall become due and payable without further action or notice.
        Notwithstanding the foregoing, a Default under clause (3) above is not an Event of Default until the trustee notifies us, or the holders of at least 25% in principal amount of the then outstanding notes notify us and the trustee, of the Default, and we fail to cure the Default within 90 days after receipt of the notice. The notice must specify the Default, demand that it be remedied and state that the notice is a "Notice of Default."
        Holders of not less than a majority in aggregate principal amount of the then outstanding notes by notice to the trustee may on behalf of the holders of all of the notes waive any existing Default or Event of Default and its consequences under the indenture, except a continuing Default or Event of Default in the payment of the principal of, premium, if any, or interest on, the notes (including in connection with an offer to purchase) (provided, however, that the holders of a majority in aggregate principal amount of the then outstanding notes may rescind an acceleration and its consequences, including any related payment Default that resulted from such acceleration). Upon any such waiver, such Default shall cease to exist, and any Event of Default arising therefrom shall be deemed to have been cured for every purpose of the indenture; but no such waiver shall extend to any subsequent or other Default or impair any right consequent thereon.
Modification and Waiver





        We and the trustee may supplement or amend the indenture with respect to the notes with the consent of the holders of at least a majority in principal amount of the outstanding notes. Without the consent of the holder of each note affected, however, no modification may:
reduce the principal amount of the outstanding notes whose holders must consent to an amendment, supplement or waiver;
reduce the principal of or change the fixed maturity of any notes or alter any of the provisions with respect to the redemption of the notes;
reduce the rate of or change the time for payment of interest on any note;
waive a Default or Event of Default in the payment of principal of, or interest or premium, if any, on the notes (except a rescission of acceleration of the notes by the holders of at least a majority in aggregate principal amount of the then outstanding notes and a waiver of the payment Default that resulted from such acceleration);
make any note payable in money other than that stated in the note;
make any change in the provisions of the indenture relating to waivers of past Defaults or the rights of holders of notes to receive payments of principal of, or interest or premium, if any, on the notes;
waive a redemption payment with respect to any note;
cause the notes to become subordinated in right of payment to any other Indebtedness; or
make any change in the foregoing amendment and waiver provisions.
        We and the trustee may supplement or amend the indenture or waive any provision of that indenture without the consent of any holders of the notes in certain circumstances, including:
to cure any ambiguity, defect or inconsistency;
to provide for uncertificated notes in addition to or in place of certificated notes or to alter the provisions of the indenture related to the forms of notes (including the related definitions) in a manner that does not adversely affect any holder in any material respect;
to provide for the assumption of our obligations to the holders of the notes by a successor to us pursuant to provisions of the indenture described under "Consolidation, Merger and Sale of Assets";
to make any change that would provide any additional rights or benefits to the holders of the notes or that does not adversely affect the legal rights hereunder of any such holder in any material respect or to surrender any right or power conferred upon us;
to comply with requirements of the SEC in order to effect or maintain the qualification of the indenture under the Trust Indenture Act;
to change or eliminate any of the provisions of the indenture; provided that any such change or elimination becomes effective only when there are no outstanding notes created prior to the execution of such amendment or supplemental indenture that is adversely affected in any material respect by the change in or elimination of the provision;
to supplement any of the provisions of the indenture to such extent necessary to permit or facilitate the defeasance and discharge of notes pursuant to the indenture; provided, that any such action does not adversely affect the interest of the holders of the notes in any material respect;
to evidence and provide the acceptance of the appointment of a successor trustee pursuant to the terms thereof; and
to add a guarantor of the notes.
        The holders of a majority in principal amount of the outstanding notes may waive any existing or past Default or Event of Default with respect to those notes. Those holders may not, however, waive any Default or Event of Default in any payment on any note or compliance with a provision that cannot be amended or supplemented without the consent of each holder affected.
Defeasance and Discharge
        Defeasance.    When we use the term "defeasance," we mean discharge from some or all of our obligations under the indenture. If we deposit with the trustee under the indenture any combination of money or government securities sufficient to make payments on the notes issued under the indenture on the dates those payments are due, then, at our option, either of the following will occur:
we will be discharged from our obligations with respect to notes ("legal defeasance"); or





we will no longer have any obligation to comply with specified restrictive covenants with respect to the notes, the covenant described under "Consolidation, Merger and Sales of Assets" and other specified covenants under the indenture, and the related Events of Default will no longer apply ("covenant defeasance").
        If the notes are defeased, the holders of the notes will not be entitled to the benefits of the indenture, except for obligations to authenticate and deliver temporary securities, register the transfer or exchange of notes, replace mutilated, destroyed, lost and stolen notes and maintain paying agencies. In the case of covenant defeasance, our obligation to pay principal, premium and interest on the notes will also survive.
        We will be required to deliver to the trustee an opinion of counsel that the deposit and related defeasance would not cause the holders of the notes to recognize income, gain or loss for U.S. federal income tax purposes and that the holders would be subject to U.S. federal income tax on the same amounts, in the same manner and at the same times as would have been the case if the deposit and related defeasance had not occurred. If we elect legal defeasance, that opinion of counsel must be based upon a ruling from the U.S. Internal Revenue Service or a change in law to that effect.
        Satisfaction and Discharge.    In addition, the indenture will cease to be of further effect with respect to the notes, subject to exceptions relating to compensation and indemnity of the trustee under the indenture and repayment to us of excess money or government securities, when:
either
all such notes theretofore authenticated and delivered (other than (i) such notes which have been destroyed, lost or stolen and which have been replaced or paid as provided in the indenture and (ii) such notes for whose payment money has theretofore been deposited in trust or segregated and held in trust by us and thereafter repaid to us or discharged from such trust, as provided in the indenture) have been delivered to the trustee for cancellation; or
all such notes not theretofore delivered to the trustee for cancellation:
have become due and payable,
will become due and payable at their Stated Maturity within one year, or
are to be called for redemption within one year under arrangements satisfactory to the trustee for the giving of notice of redemption by the trustee in our name and at our expense;
and we, in the case of the three preceding bullets, have deposited or caused to be deposited with the trustee, as funds in trust for such purpose, an amount in U.S. dollars or U.S. government obligations maturing as to principal and interest in such amounts and at such times as will, together with any interest thereon (but without consideration of the reinvestment of such interest), be sufficient to pay and discharge the entire Indebtedness on such notes not theretofore delivered to the trustee for cancellation, for principal and any premium and interest to the date of such deposit (in the case of notes which have become due and payable) or to the Stated Maturity or redemption date, as the case may be;
we have paid or caused to be paid all other sums payable by us with respect to the notes; and
we have delivered to the trustee an Officers' Certificate and an opinion of counsel, each stating that all conditions precedent provided in the indenture or relating to the satisfaction and discharge of the indenture with respect to such notes have been complied with.
The Trustee
        Deutsche Bank Trust Company Americas is the trustee under the indenture. Deutsche Bank Trust Company Americas and its affiliates may perform certain commercial banking services for us from time to time for which they receive customary fees.
        The Trust Indenture Act contains limitations on the rights of the trustee, if it or any of its affiliates is then our creditor, to obtain payments of claims or to realize on certain property received for any such claim, as security or otherwise. The trustee and its affiliates are permitted to engage in other transactions with us. If, however, the trustee acquires any conflicting interest, it must eliminate that conflict or resign within 90 days after ascertaining that it has a conflicting interest and after the occurrence of a Default under the indenture, unless the Default has been cured, waived or otherwise eliminated within the 90-day period.





Payment; Paying Agents and Transfer Agents
The trustee has been appointed as paying agent and transfer agent for the notes. Payments on the notes will be made in U.S. dollars at the office of the trustee and any paying agent. At our option, however, payments may be made by wire transfer for notes held in book-entry form or by check mailed to the address of the Person entitled to the payment as it appears in the security register.
If the principal of or any premium or interest on the notes is payable on a day that is not a business day, the payment will be made on the following business day. Subject to the requirements of any applicable abandoned property laws, the trustee and paying agent will pay to us upon written request any money held by them for payments on the notes that remains unclaimed for three years after the date upon which that payment has become due. After payment to us, holders entitled to the money must look to us for payment. In that case, all liability of the trustee or paying agent with respect to that money will cease.
Definitions
        "Attributable Indebtedness," when used with respect to any Sale/Leaseback Transaction, means, as at the time of determination, the present value (discounted at the rate set forth or implicit in the terms of the lease included in such transaction) of the total obligations of the lessee for rental payments (other than amounts required to be paid on account of taxes, maintenance, repairs, insurance, assessments, utilities, operating and labor costs and other items which do not constitute payments for property rights) during the remaining term of the lease included in such Sale/Leaseback Transaction (including any period for which such lease has been extended). In the case of any lease which is terminable by the lessee upon the payment of a penalty, such net amount shall be the lesser of the net amount determined assuming termination upon the first date such lease may be terminated (in which case the net amount shall also include the amount of the penalty, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated) or the net amount determined assuming no such termination.
        "Bankruptcy Act" means the Bankruptcy Act or Title 11 of the United States Code, as amended.
        "Board of Directors" means our Board of Directors or comparable governing body or any committee thereof duly authorized, with respect to any particular matter, to act by or on behalf of our Board of Directors or comparable governing body.
        "Capitalized Lease Obligation" of any Person means any obligation of such Person to pay rent or other amounts under a lease of property, real or personal, that is required to be accounted for as a capital lease for financial reporting purposes in accordance with GAAP; and the amount of such obligation shall be the capitalized amount thereof determined in accordance with GAAP.
        "Consolidated Net Tangible Assets" means the total amount of assets (after deducting applicable reserves and other properly deductible items) less:
all current liabilities (excluding liabilities that are extendible or renewable at our option to a date more than 12 months after the date of calculation and excluding current maturities of long-term Indebtedness); and
all goodwill, trade names, trademarks, patents, unamortized debt discount and expense and other like intangible assets.
        We will calculate our Consolidated Net Tangible Assets based on our most recent quarterly balance sheet and in accordance with GAAP.
        "Default" means any event, act or condition that is, or after notice or the passage of time or both would be, an Event of Default.
        "Entity" means a corporation, limited liability company or business trust (or functional equivalent of the foregoing under applicable foreign law).
        "Funded Indebtedness" means all Indebtedness that matures on or is renewable to a date more than one year after the date the Indebtedness is incurred.
        "GAAP" means United States generally accepted accounting principles and policies consistent with those applied in the preparation of our financial statements.
        "Indebtedness" means:





all indebtedness for borrowed money (whether full or limited recourse);
all obligations evidenced by bonds, debentures, notes or other similar instruments;
all obligations under letters of credit or other similar instruments, other than standby letters of credit, performance bonds and other obligations issued in the ordinary course of business, to the extent not drawn or, to the extent drawn, if such drawing is reimbursed not later than the third business day following demand for reimbursement;
all obligations to pay the deferred and unpaid purchase price of property or services, except trade payables and accrued expenses incurred in the ordinary course of business;
all Capitalized Lease Obligations;
all Indebtedness of others secured by a Lien on any asset of the Person in question (provided that if the obligations so secured have not been assumed in full or are not otherwise fully the Person's legal liability, then such obligations may be reduced to the value of the asset or the liability of the Person); or
all Indebtedness of others (other than endorsements in the ordinary course of business) guaranteed by the Person in question to the extent of such guarantee.
        "Issue Date" means September 29, 2014, the date on which the notes were first authenticated and delivered under the indenture.
        "Joint Venture" means any partnership, corporation or other entity in which up to and including 50% of the partnership interests, outstanding voting stock or other equity interests is owned, directly or indirectly, by us and/or one or more Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Lien" means any mortgage, pledge, lien, charge, security interest or similar encumbrance. For purposes of the indenture, we or any of our Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, Capitalized Lease Obligation or other title retention agreement relating to such asset.
        "Maturity" when used with respect to any notes, means the date on which the principal of such note or an installment of principal becomes due and payable as therein or herein provided, whether at the Stated Maturity or by declaration of acceleration, call for redemption or otherwise.
        "Officers" means our Chairman of the Board, President, Vice President, Treasurer, Controller, Secretary, Assistant Treasurer, Assistant Controller or Assistant Secretary.
        "Officers' Certificate" means a certificate signed by two Officers and delivered to the trustee, which certificate shall be in compliance with the indenture.
        "Pari Passu Indebtedness" means any of our Indebtedness, whether outstanding on the Issue Date or thereafter created, incurred or assumed, unless, in the case of any particular Indebtedness, the instrument creating or evidencing the same or pursuant to which the same is outstanding expressly provides that such Indebtedness shall be subordinated in right of payment to the notes.
        "Permitted Liens" shall mean (i) Liens existing on the Issue Date; (ii) Liens on property or assets of, or any shares of stock of, or other equity interests in, or Indebtedness of, any Person existing at the time such Person becomes a Subsidiary of us or at the time such Person is merged into or consolidated with us or any of our Subsidiaries or at the time of a sale, lease or other disposition of the properties of a Person (or a division thereof) as an entirety or substantially as an entirety to us or a Subsidiary, and not incurred in contemplation of such merger, consolidation, sale, lease or other disposition; (iii) Liens in favor of us or any of our Subsidiaries or Liens securing debt of a Subsidiary owing to us or to another Subsidiary; (iv) Liens in favor of governmental bodies to secure partial, progress, advance or other payments or performance pursuant to the provisions of any contract or statute; (v) Liens securing industrial revenue, pollution control or similar revenue bonds; (vi) Liens on assets existing at the time of acquisition thereof, securing all or any portion of the cost of acquiring, constructing, improving, developing, expanding or repairing such assets or securing Indebtedness incurred prior to, at the time of, or within 24 months after, the later of the acquisition, the completion of construction, improvement, development, expansion or repair or the commencement of commercial operation of such assets, for the purpose of (a) financing all or any part of the purchase price of such assets or (b) financing all or any part of the cost of construction, improvement, development, expansion or repair of any such assets; (vii) statutory liens or landlords', carriers', warehouseman's, mechanics', suppliers', materialmen's, repairmen's, maritime or other like Liens arising in the ordinary course of business and with respect to amounts not yet delinquent





or being contested in good faith by appropriate proceedings; (viii) Liens in connection with in rem and other legal proceedings, which are being contested in good faith; (ix) Liens securing taxes, assessments, government charges or levies not yet due or delinquent, or which can thereafter be paid without penalty, or which are being contested in good faith by appropriate proceedings; (x) Liens on the stock, partnership or other equity interest of us or any Subsidiary in any Joint Venture or any Subsidiary that owns an equity interest in such Joint Venture to secure Indebtedness, provided the amount of such Indebtedness is contributed and/or advanced solely to such Joint Venture; (xi) Liens incurred in the ordinary course of business to secure performance of tenders, bids or contracts entered into in the ordinary course of business, including without limitation any rights of offset or liquidated damages, penalties, or other fees that may be contractually agreed to in conjunction with any tender, bid, or contract entered into by us or any of our Subsidiaries in the ordinary course of business; (xii) Liens on current assets of us or any of our Subsidiaries securing our Indebtedness or Indebtedness of any such Subsidiary, respectively; (xiii) deposits made in connection with maintaining self-insurance, to obtain the benefits of laws, regulations or arrangements relating to unemployment insurance, old age pensions, social security or similar matters or to secure surety, appeal or customs bonds; and (xiv) any extensions, substitutions, replacements or renewals in whole or in part of a Lien enumerated in clauses (i) through (xiii) above, provided that the amount of Indebtedness secured by such extension, substitution, replacement or renewal shall not exceed the principal amount of Indebtedness being substituted, extended, replaced or renewed, together with the amount of any premiums, fees, costs and expenses associated with such substitution, extension, replacement or renewal, nor shall the pledge, mortgage or lien be extended to any additional Principal Property unless otherwise permitted under the covenant described under "Limitation on Liens."
        "Person" means any individual, corporation, partnership, limited liability company, joint venture, incorporated or unincorporated association, joint stock company, trust, unincorporated organization or government or other agency or political subdivision thereof or other entity of any kind.
        "Principal Property" means any drilling rig or drillship, or integral portion thereof, owned or leased by us or any Subsidiary and used for drilling offshore oil and gas wells, which, in the opinion of the Board of Directors, is of material importance to the business of us and our Subsidiaries taken as a whole, but no such drilling rig or drillship, or portion thereof, shall be deemed of material importance if its net book value (after deducting accumulated depreciation) is less than 2% of Consolidated Net Tangible Assets.
        "Sale/Leaseback Transaction" means any arrangement with any Person pursuant to which we or any Subsidiary leases any Principal Property that has been or is to be sold or transferred by us or the Subsidiary to such Person, other than (1) temporary leases for a term, including renewals at the option of the lessee, of not more than five years; (2) leases between us and a Subsidiary or between Subsidiaries; and (3) leases of Principal Property executed by the time of, or within 12 months after the latest of, the acquisition, the completion of construction, alteration, improvement or repair, or the commencement of commercial operation of the Principal Property.
        "Stated Maturity" when used with respect to any note or any installment of principal thereof or interest thereon, means the date specified in such note as the fixed date on which the principal of such note or such installment of principal or interest is due and payable.
        "Subsidiary" means a Person at least a majority of the outstanding Voting Stock of which is owned, directly or indirectly, by us or by one or more other Subsidiaries, or by us and one or more other Subsidiaries. A Joint Venture is not treated as a Subsidiary.
        "Voting Stock" means, with respect to any Person, securities of any class or classes of capital stock of such Person entitling the holders thereof (whether at all times or at the times that such class of capital stock has voting power by reason of the happening of any contingency) to vote in the election of members of the board of directors or comparable body of such Person.
        "Wholly Owned Subsidiary" means, with respect to a Person, any Subsidiary of that Person to the extent
all of the Voting Stock of such Subsidiary, other than any director's qualifying shares mandated by applicable law, is owned directly or indirectly by such Person or
such Subsidiary is organized in a foreign jurisdiction and is required by the applicable laws and regulations of such foreign jurisdiction to be partially owned by another Person, if such Person:
directly or indirectly owns the remaining capital stock of such Subsidiary and





by contract or otherwise, controls the management and business of such Subsidiary and derives the economic benefits of ownership of such Subsidiary to substantially the same extent as if such Subsidiary were a Wholly Owned Subsidiary.




Exhibit 10.28

AMENDMENT NO. 6 TO THE
ENSCO 2005 SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
(As Amended and Restated Effective January 1, 2005)

THIS AMENDMENT No. 6 is executed this 19th day of December 2019, and effective as 4 November 2019, by ENSCO International Incorporated, having its principal office in Houston, Texas (hereinafter referred to as the “Company”).
WITNESSETH:
WHEREAS, effective April 1, 1995, Energy Service Company, Inc. adopted the Energy Service Company, Inc. Select Executive Retirement Plan (the “Original SERP”);
WHEREAS, the name of the Company was changed to ENSCO International Incorporated;
WHEREAS, the Company amended and restated the Original SERP, effective January 1, 1997, to (i) provide a discretionary profit sharing contribution, (ii) rename the Original SERP the “ENSCO Supplemental Executive Retirement Plan,” and (iii) coordinate the operation of the Original SERP with the ENSCO Savings Plan;
WHEREAS, the Pension and Welfare Benefits Administration of the Department of Labor issued final regulations establishing new standards for processing benefit claims of participants and beneficiaries under Section 8.2 of the Original SERP which were subsequently clarified by further guidance from the Pension and Welfare Benefits Administration (collectively the “Final Claims Procedure Regulations”);
WHEREAS, the Company adopted Amendment No. 1 to the amended and restated Original SERP, effective as of January 1, 2002, to revise Section 8.2 of the Original SERP to provide that the administrator of the Original SERP shall process benefit claims of participants and beneficiaries pursuant to the claims procedure specified in the summary plan description for the Original SERP which shall comply with the Final Claims Procedure Regulations, as may be amended from time to time;
WHEREAS, the Company amended and restated the Original SERP, effective as of January 1, 2004;
WHEREAS, the American Jobs Creation Act of 2004 (the “AJCA”) enacted new section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), which imposed new rules regarding the timing of elections and distributions under nonqualified deferred compensation plans effective for years beginning after December 31, 2004;
WHEREAS, the Company determined to comply with the AJCA and new section 409A of the Code by freezing the Original SERP and adopting the ENSCO 2005 Supplemental Executive Retirement Plan (the “2005 SERP”), effective January 1, 2005;
WHEREAS, the Board of Directors of the Company (the “Board”), upon recommendation of its Nominating, Governance and Compensation Committee (the “Committee”), approved Amendment No. 1 to the 2005 SERP during a regular meeting held on November 6, 2007;





WHEREAS, the Board, upon recommendation of the Committee, approved Amendment No. 2 to the 2005 SERP during a regular meeting held on March 10, 2008;
WHEREAS, the Board, upon recommendation of the Committee during its meeting held on November 3-4, 2008, approved the amendment and restatement of the 2005 SERP during a regular meeting held on November 4, 2008;
WHEREAS, the Company adopted the amended and restated 2005 SERP, effective as of January 1, 2005, except as specifically provided otherwise to the contrary therein, in order to (i) facilitate compliance with the final Treasury regulations under section 409A of the Code, and (ii) incorporate the amendments to the 2005 SERP previously made by Amendment No. 1 and Amendment No. 2;
WHEREAS, the Board, upon recommendation of the Committee during its regular meeting held on August 4, 2009, approved Amendment No. 1 to the 2005 SERP, as amended and restated effective January 1, 2005, during a regular meeting held on August 4, 2009;
WHEREAS, the Board, upon recommendation of the Committee during its regular meeting held on November 2, 2009, approved Amendment No. 2 to the 2005 SERP, as amended and restated effective January 1, 2005, during a regular meeting held on November 3, 2009;
WHEREAS, the Board, upon recommendation of the Committee, approved Amendment No. 3 to the 2005 SERP, as amended and restated January 1, 2005, on December 22, 2009;
WHEREAS, each issued and outstanding American depositary share ("ADS") (each ADS representing a Class A ordinary share, nominal value US$0.10 of Ensco plc, now named Valaris plc and with a nominal value of US$0.40 per share, (each a "Valaris UK Share")) was converted into the right to receive a Valaris UK Share effective as of the date fixed for termination of the Deposit Agreement, dated as of September 29, 2009, among Ensco plc, Citibank, N.A., as Depositary, and the holders and beneficial owners of the ADSs issued thereunder (the "Termination Date");
WHEREAS, the Board, upon recommendation of the Committee, by its unanimous written consent approved Amendment No. 4 to the amended and restated 2005 SERP, effective as of the Termination Date in order to (i) specifically provide that (A) each ADS held by the Ensco ADS fund on the Termination Date will be converted into one Valaris UK Share, and (B) the references to "Ensco ADS fund" in Section 7.2 of the amended and restated 2005 SERP shall thereafter be read and considered to be references to the "Ensco UK Stock fund," and (ii) make such other conforming changes to the amended and restated 2005 SERP as determined necessary;
WHEREAS, the Board, upon recommendation of the Committee during its regular meeting held on 20 May 2013, approved Amendment No. 5 to the amended and restated 2005 SERP, during a regular meeting held on 21 May 2013;
WHEREAS, the Compensation Committee of the Board of Directors of Valaris plc, the parent of the Company, pursuant to its delegated authority under its charter approved Amendment No. 6 to the amended and restated 2005 SERP during a regular meeting held on 4 November 2019; and
WHEREAS, the Company now desires to adopt this Amendment No. 6 to the amended and restated 2005 SERP in order to freeze the amended and restated 2005 SERP as to the entry of





new participants effective as of 4 November 2019 and as to future deferrals and contributions thereunder effective as of 1 January 2020 and to make certain other conforming changes to reflect recent changes in the name of Ensco UK and its Class A ordinary shares.
NOW, THEREFORE, in consideration of the premises and the covenants herein contained, and in accordance with Section 10.1 of the amended and restated 2005 SERP, the Company hereby adopts the following Amendment No. 6 to the amended and restated 2005 SERP, effective as of 4 November 2019:

1.
A new sentence is added to the end of Section 3.1 of the amended and restated 2005 SERP to read as follows:

“Notwithstanding any other provision of the Plan to the contrary, no Employee who, as of 4 November 2019, was not a Participant in the Plan shall be eligible to participate in the Plan.”

2.
A new Section 4.7 is hereby added to the amended and restated 2005 SERP to read as follows:

“Notwithstanding any other provision of the Plan to the contrary, no contributions or deferrals, including Automatic Deferrals, Basic Deferrals, Discretionary Deferrals, Matching Contributions, and Employer Discretionary Contributions, shall be credited under the Plan on or following 1 January 2020. Each Participant shall continue to accrue earnings and losses on and to vest in Deferred Compensation, Employer Discretionary Contributions and Matching Contributions credited to such Participant’s Account prior to such date in accordance with the terms of the Plan.”

3.
All references to “Ensco UK” shall refer to “Valaris plc” and all references to an “Ensco UK Shares” shall refer to a Class A ordinary shares of Valaris plc, par value $0.40 per share.

4.
A new sentence is added to the end of Section 7.2 of the Plan to read as follows:

“No new investments into the Company stock fund shall be permitted under this Plan on or after 1 January 2020.”

[Signature page follows.]





IN WITNESS WHEREOF, the Company, acting by and through its duly authorized officers, has caused this Amendment No. 6 to the amendment and restatement of the ENSCO 2005 Supplemental Executive Retirement Plan to be executed on the date first above written.
 
 
ENSCO INTERNATIONAL INCORPORATED
 
/s/ Roger C. McCartney
By: Roger C. McCartney
Title: Director







Exhibit 10.59

December 3, 2019
Valaris plc
Attn: Michael T. McGuinty
Senior Vice President and General Counsel
6 Chesterfield Gardens
London, England W1J 5BQ

Re:    Voluntary Reduction of Base Salary effective as of January 1, 2020

Dear Michael,
I refer to Section 2(a) of my October 7, 2018 Employment Agreement (the “Employment Agreement”) with ENSCO Global Resources Limited and Ensco plc, now known as Valaris plc (“Valaris”), which provides that during the term of the Employment Agreement, “[I] shall receive a base salary pursuant to [the] Agreement at an annual rate equal to $950,000 per annum” and that “the Base Salary may not be reduced without [my] express consent.”
By this letter, I hereby request and expressly consent to a 10% reduction of my Base Salary, which reduction shall result in my Base Salary being $855,000 per annum commencing effective as of January 1, 2020. I expressly acknowledge and agree that this reduction of my Base Salary will result in a corresponding reduction to: (i) my Annual Bonus opportunity under Section 2(b) of the Employment Agreement; (ii) my Annual Equity Award under Section 2(d) of the Employment Agreement; and (iii) my severance entitlements under Section 4(b) of the Employment Agreement.
By this letter, I hereby voluntarily and expressly waive any rights to claim “Good Reason,” “constructive termination” or any similar concept as a result of this reduction to my Base Salary under the common law, the Employment Agreement, my Change in Control Agreement entered into with Rowan Companies, Inc. effective as of April 25, 2014, and all equity award agreements that I have entered into with Valaris plc (or its predecessors).
Except as expressly set forth herein, no other provisions of the Employment Agreement shall be modified by this letter and the Employment Agreement otherwise remains in full force and effect in accordance with its terms.
Sincerely,

Dr. Thomas Burke




Exhibit 10.60

CONSULTING AGREEMENT

This Consulting Agreement (“Agreement”) is by and between ENSCO Incorporated (the “Company”), and Patrick Carey Lowe (“Consultant”). This Agreement is entered into on December 31, 2019 and shall be effective as of January 1, 2020 (“Effective Date”).

RECITALS

The Company wishes to utilize certain services performed by Consultant, and Consultant can provide and desires to render to the Company such services, and the parties agree that it would be to their mutual advantage to execute this Agreement and thereby define the terms and conditions that will control the rendering of services provided to the Company by Consultant.
In consideration of the promises and mutual covenants in this Agreement, the Company and Consultant hereby agree as follows:
I.
Services to be Provided by Consultant

A.Description of Consulting Services. Subject to the terms of this Agreement, the Company retains Consultant, and Consultant agrees to serve as a consultant to the Company and its affiliates for the purpose of providing part-time transitional support and general consulting services to the Company and its affiliates on such matters as the Company may reasonably request (made by the Company’s Chief Executive Officer) from time to time, all at such times and location(s) as are mutually agreeable Consultant and the Company (collectively, the “Consulting Services”). The Consulting Services shall not exceed twenty (20) hours per month unless otherwise mutually agreed upon by the parties. During the Term, Consultant shall be entitled to accept other engagements or employment and pursue other activities and interests, so long as such employment, activities and interests do not otherwise unreasonably conflict with his obligations hereunder.

B.Company’s Reliance. The Company is entering into this Agreement in reliance on Consultant’s special and unique abilities in rendering the Consulting Services and Consultant will use Consultant’s best effort, skill, judgment, and ability in rendering the Consulting Services.

C.Representations by Consultant. Consultant represents to the Company that Consultant is under no contractual, legal or fiduciary obligation or burden that reasonably may be expected to interfere with Consultant’s ability to perform the Consulting Services in accordance with the Agreement’s terms, including without limitation any agreement or obligation to or with any other company, and that Consultant is not bound by the terms of any agreement with any previous employer or other party to refrain from using or disclosing any trade secret or confidential or proprietary information in the course of Consultant’s engagement by the Company or to refrain from competing, directly or indirectly, with the business of any other party. Consultant agrees that Consultant will not use, distribute or provide to anyone at the Company any confidential or proprietary information belonging to any other company or entity, at any time during Consultant’s performance under this Agreement. Consultant further represents that Consultant’s performance of the Consulting Services will not breach any agreement to keep in confidence proprietary information, knowledge or data acquired by Consultant in confidence or in trust prior to this Agreement, and Consultant will not disclose to the Company or induce the Company to use any confidential or proprietary information or material belonging to any other party.

D.Nature of Relationship Between Parties. Consultant will render the Consulting Services under this Agreement as an independent contractor, while specifically adhering to the rules, policies, regulations and procedures of the Company, as may be amended by the Company at any time. Except as otherwise specifically agreed to by the Company in writing, Consultant shall have no authority or power to bind the Company with respect to third parties, and Consultant shall not represent to third parties that Consultant has





authority or power to bind the Company. It is not the intention of the parties to this Agreement to create, by virtue of this Agreement, any employment relationship, trust, partnership, or joint venture between Consultant and the Company or any of its affiliates, to make them legal representatives or agents of each other or to create any fiduciary relationship or additional contractual relationship among them.

II.
COMPENSATION FOR CONSULTING SERVICES

A.Consulting Fee. In exchange for the Consulting Services, the Company shall pay Consultant an aggregate consulting fee of $1,178,000 (the “Consulting Fee”), which amount shall be payable in arrears in twelve (12) monthly installments following the Effective Date, with the first eleven (11) installments in the amount of $98,166.67 each and the final installment in the amount of $98,166.63. Each monthly installment shall be paid within fifteen (15) days after the applicable month-end to the bank account designated by Consultant. The Consulting Fee constitutes the sole compensation to which Consultant shall be entitled for performance of the Consulting Services.

B.Expense Reimbursement. Consultant will be reimbursed for reasonable, documented out of pocket travel and business expenses incurred in the performance of the Consulting Services in accordance with the Company’s travel and expense policies. Any reimbursement will be made within 30 days of submission of appropriate documentation of such costs by Consultant to the Company.

C.Benefits. Consultant shall at all times be an independent contractor (and not an employee or agent of the Company); therefore, during the Term, Consultant shall not be entitled to participate in any benefit plans or programs that the Company provides or may provide to its employees, including, but not limited to, pension, profit-sharing, medical, dental, workers’ compensation, occupational injury, life insurance and vacation or sick benefits. Notwithstanding the foregoing, the foregoing shall not operate to limit any rights Consultant may have to continued benefits coverage by virtue of prior employment with any affiliate of the Company.

D.Workers’ Compensation. Consultant understands and acknowledges that the Company shall not obtain workers’ compensation insurance covering Consultant.

III.
PAYMENT OF TAXES

A.Federal, State, and Local Taxes. Neither federal, state, or local income tax nor social security tax nor payroll tax of any kind (collectively “Taxes”) will be withheld or paid by the Company or any of its affiliates on behalf of Consultant. Consultant will not be treated as an employee of the Company or any of its affiliates with respect to the Consulting Services for federal, state, or local tax purposes.

B.Notices to Consultant About Tax Duties And Liabilities. Consultant understands that Consultant is responsible to pay, according to the applicable law, Consultant’s Taxes. The parties agree that any tax consequences or liability arising from the Company’s payments to Consultant shall be the sole responsibility of Consultant. Should any local, state, or federal taxing authority determine that any of the payments under Sections II(A) or (B) constitute income subject to withholding under any federal, state, or local law, then Consultant agrees to indemnify and hold the Company harmless for any and all Tax liability, including, but not limited to, Taxes, levies, assessments, fines, interest, costs, expenses, penalties, and attorneys’ fees.

IV.
INDEMNIFICATIONS AND COVENANTS

A.Limitations on the Company’s Liability and Consultant’s Indemnification of the Company. By entering into this Agreement and receiving the Consulting Services, but subject to the other Agreement terms, the Company will not be liable for any Damages (defined below) caused by Consultant’s dishonesty, willful misconduct, or gross negligence or for Consultant’s breach of this Agreement. Consultant shall indemnify and hold harmless the Company from and against all losses, judgments, damages, expenses





(including, without limitation, reasonable fees and expenses of counsel), liabilities, and amounts paid in settlement (collectively “Damages”) incurred by or asserted against the Company arising from, as a result of, in connection with, or relating to Consultant’s dishonesty, willful misconduct, or gross negligence in performing any Consulting Services or for Consultant’s breach of this Agreement.

B.Consultant’s Standard of Care. Subject to the other Agreement provisions, Consultant will provide all Consulting Services with the same degree of care, skill, and prudence that would be customarily exercised in the Company’s best interest.

C.Confidential Information; Non-Disclosure; Non-Solicitation; Non-Competition and Work Product Ownership.

(i)    Confidential Information. Consultant has previously received and will continue to have access to the Company’s trade secrets and other confidential information which is not known to the Company’s competitors or within the Company’s industry generally, which was developed by the Company over a long period of time and/or at its substantial expense, and which is of great competitive value to the Company (collectively “Confidential Information”). For purposes of this Agreement, “Confidential Information” includes all confidential or proprietary information (whether tangible, intangible, written, oral, electronic, or other) of the Company or its affiliates. Such confidential or proprietary information shall include, but shall not be limited to, all trade secrets and the following items (as well as all information relating to the following items): (a) all confidential or competitively sensitive information relating to the business of the Company or its subsidiaries and affiliates, (b) all intellectual property and proprietary rights of the Company or its subsidiaries and affiliates (including, without limitation, the Intellectual Property), (c) computer codes and instructions, processing systems and techniques, inputs and outputs (regardless of the media on which stored or located) and hardware and software configurations, designs, architecture and interfaces, (d) business research, studies, procedures, costs, plans and strategies, (e) financial data, budgets and plans, (f) distribution methods, plans and strategies, (g) marketing data, research, methods, plans, strategies and efforts, (h) information regarding actual and prospective suppliers and customers (including lists, profiles, identities of and customer nonpublic personal information), (i) the terms of contracts and agreements with, the needs and requirements of, and the Company’s course of dealing with, actual or prospective suppliers and customers, (j) personnel information (including the names, contact information, skills and compensation of employees, contractors and other service providers of the Company), (k) customer and vendor credit information, (l) information received from third parties subject to obligations of non-disclosure or non-use, (m) costs, pricing and pricing strategies, (n) audit processes, management methods and information, reports, recommendations and conclusions, and (o) development tools, techniques and processes and training methods and manuals. Failure by the Company to mark any of the Confidential Information as confidential or proprietary shall not affect its status as Confidential Information. For purposes of this Agreement, “Intellectual Property” means: (a) all inventions (whether patentable or unpatentable and whether or not reduced to practice), all improvements thereto, and all patents and patent applications claiming such inventions, (b) all trademarks, service marks, trade dress, logos, trade names, fictitious names, brand names, brand marks and corporate names, together with all translations, adaptations, derivations, and combinations thereof and including all goodwill associated therewith, and all applications, registrations, and renewals in connection therewith, (c) all copyrightable works, all copyrights, and all applications, registrations, and renewals in connection therewith, (d) all mask works and all applications, registrations, and renewals in connection therewith, (e) all trade secrets (including research and development, know how, formulas, compositions, manufacturing and production processes and techniques, methodologies, technical data, designs, drawings and specifications), (f) all computer software (including data, source and object codes and related documentation), (g) all other proprietary rights, (h) all copies and tangible embodiments thereof (in whatever form or medium), or (i) similar intangible personal property which have been or are developed or created in whole or in part by the Consultant (1) at any time and at any place while the Consultant is providing services to the Company and which, in the case of any or all of the foregoing, are related to and used in connection with the business of the Company or (2) as a result of tasks assigned to the Consultant by the Company.






(ii)
Non-Disclosure.

(a)    In exchange for the Company’s agreement to provide Consultant with Confidential Information and to protect the Company’s legitimate business interests, Consultant shall hold all Confidential Information in strict confidence. Consultant shall not, during the Term or at any time thereafter, disclose to anyone, or publish, use for any purpose, exploit, or allow or assist another person to use, disclose or exploit, except for the benefit of the Company, without prior written authorization of the Company, any Confidential Information or part thereof, except as permitted: (1) in the ordinary course of the Company’s business or Consultant’s work for the Company; or (2) by law. Consultant shall use all reasonable precautions to assure that all Confidential Information is properly protected and kept from unauthorized persons.

(b)    Consultant agrees that Consultant shall not use or disclose any confidential or trade secret information belonging to any former employer or third party, and Consultant shall not bring onto the premises of the Company or onto any Company property any confidential or trade secret information belonging to any former employer or third party without such third parties’ consent.

(c)    During the Term, the Company will receive from third parties their confidential and/or proprietary information, subject to a duty on the Company’s part to maintain the confidentiality of and to use such information only for certain limited purposes. Consultant agrees to hold all such confidential or proprietary information in the strictest confidence and not to disclose it to any person or organization or to use it except as necessary in the course of Consultant’s Consulting Services with the Company and in accordance with the Company’s agreement with such third party.
        
(d)     Notwithstanding the foregoing, if Consultant makes a confidential disclosure of a trade secret or other confidential information to a government official or an attorney for the sole purpose of reporting a suspected violation of law, or in a court filing under seal, Consultant shall not be held liable under this Agreement or under any federal or state trade secret law for such a disclosure.

(iii)Non-Solicitation. Consultant hereby agrees that during the Term and for a period of twelve (12) months thereafter (the “Restricted Period”), Consultant will not, directly or indirectly, induce or attempt to induce, or cause or solicit any officer, manager, contractor or employee of the Company or its affiliates to cease their relationship with the Company or its affiliates or hire or engage any such officer, manager, contractor or employee of the Company or its affiliates, or in any way materially interfere with the relationship between the Company and its affiliates, on the one hand, and any such officer, manager, contractor or employee, on the other hand. Notwithstanding the foregoing, nothing in this Agreement shall prohibit Consultant from making a general, public solicitation for employment, or using an employee recruiting or search firm to conduct a search, that does not specifically target employees or consultants of the Company or its affiliates so long as no persons who were at any time during the twelve (12) month period prior to the commencement of such solicitation, employees or consultants of the Company or its affiliates are hired or otherwise engaged as a result of such general solicitations or search firm efforts. Consultant hereby agrees that during the Restricted Period, he will not, directly or indirectly, induce, or attempt to induce, cause or solicit any customer, client or supplier of the Company or its affiliates to reduce or cease doing business with the Company or its affiliates, or in any way knowingly interfere with the relationship between any customer, client or supplier of the Company or its affiliates, on the one hand, and the Company and its affiliates, on the other hand.

(iv)Non-Competition. In exchange for the Consulting Fee and the Company’s provision to Consultant of Confidential Information and to protect the Company and its affiliates’ legitimate business interests, Consultant hereby agrees that during the Restricted Period, Consultant will not, without the prior written consent of the Board of Directors of Valaris plc, directly or indirectly, provide services to, or own any interest in, manage, operate, control, or participate in the ownership, management, operation or control of, any entity engaged in offshore drilling operations (including as an employee or consultant, other than as an employee of, or consultant to, the Company or its affiliates); provided, however, that notwithstanding the foregoing, Consultant may own, directly or indirectly, solely as a passive investment, securities of any entity





traded on a national securities exchange if Consultant is not a controlling person of, or a member of a group which controls, such entity and does not, directly or indirectly, own two percent (2%) or more of any class of securities of such entity.
 
(v)    Work Product.

(a)    Prior Proprietary Information Retained and Licensed. Consultant has attached hereto as Exhibit 1 a list describing all work product, information, inventions, original works of authorship, ideas, know-how, processes, designs, computer programs, photographs, illustrations, developments, trade secrets and discoveries, including improvements Consultant conceived, created, developed, made, reduced to practice or completed, either alone or with others (collectively, “Work Product”) that Consultant: (i) made, created, developed or invented by Consultant prior to the Term; (ii) claims a proprietary right or interest in; and (iii) does not assign to the Company hereunder (collectively referred to as the “Prior Proprietary Information”). If no such list is attached or if such list indicates “none,” Consultant represents that there is no such Prior Proprietary Information. Consultant understands and agrees that the Company makes no attempt to verify Consultant’s claim of ownership to any of the Prior Proprietary Information. Consultant agrees that Consultant shall not incorporate in any work that Consultant performs for the Company any Prior Proprietary Information or any of the technology described in any Prior Proprietary Information. Nonetheless, if in the course of Consultant’s Consulting Services, Consultant incorporates into a Company product, process or machine Prior Proprietary Information, Consultant agrees to grant and hereby grants the Company a nonexclusive, royalty-free, irrevocable, sublicensable, transferable, perpetual, and worldwide license to make, have made, modify, use, have used, import, export, reproduce, distribute, prepare and have prepared derivative works of, offer to sell, sell and otherwise exploit such Prior Proprietary Information, and provided further that all of the foregoing rights of the Company shall extend to any derivative works so prepared.

(b)     Maintenance of Records. Consultant agrees to keep and maintain adequate and current hard-copy and electronic records of all Work Product made by Consultant (solely or jointly with others) during the Term. The records will be available to and remain the sole property of the Company during the Term and at all times thereafter.

(vi)    Return of Company Property.    Upon the termination of the Consulting Services under this Agreement for any reason, Consultant shall immediately return and deliver to the Company any and all Confidential Information, software, devices, data, reports, proposals, lists, correspondence, materials, equipment, computers, hard drives, papers, books, records, documents, memoranda, manuals, e-mail, electronic or magnetic recordings or data, including all copies thereof, books of account, drawings, prints, plans, and the like which belong to the Company or relate to the Company’s business and which are in Consultant’s possession, custody or control, whether prepared by Consultant or others. If at any time after termination of Consultant’s Consulting Services under this Agreement, for any reason, Consultant determines that Consultant has any Confidential Information in Consultant’s possession or control, Consultant shall immediately return to the Company all such Confidential Information in Consultant’s possession or control, including all copies and portions thereof. Further, upon termination of the Consulting Services under this Agreement for any reason, Consultant shall not retain any Confidential Information, data, information or documents belonging to the Company or any copies thereof (in electronic or hard copy format).

V.     TERM OF AGREEMENT; TERMINATION

A.    Term; Termination Payments. The term of this Agreement shall commence on the Effective Date and, subject to the following provisions of this section, shall continue until December 31, 2020 (the “Term”). The Company or Consultant may terminate this Agreement at any time for any reason or no reason and with or without advance notice. Upon any termination by Consultant other than as a result of death or disability or any termination by the Company by reason of Consultant’s gross misconduct or willful negligence, the Company shall pay the Consultant the Consulting Fee earned through the date of termination within thirty (30) days following the date of termination. Upon any termination by reason of Consultant’s death or disability or any termination by the Company for any other reason, the Company shall pay to the Consultant (or his





beneficiaries, as applicable) any unpaid installments of the Consulting Fee, in a single lump sum within thirty (30) days following the date of termination.

B.    Survival. The provisions respectively set forth in Section IV and Section VI.A. shall survive termination or expiration of this Agreement. In addition, all provisions of this Agreement, which expressly continue to operate after the termination of this Agreement or which relate to the validity, interpretation, reformation, or enforcement (including jurisdiction and venue) of this Agreement, shall survive the Agreement’s termination or expiration.

VI.    OTHER PROVISIONS

A.    Non-Disparagement. Consultant agrees that the Company’s goodwill and reputation are assets of great value to the Company which have been obtained and maintained through great costs, time and effort. Therefore, Consultant agrees that during the Term and at all times thereafter, Consultant shall not in any way disparage, libel or defame the Company, its business or business practices, its products or services, or its employees, consultants, or directors. Consultant further agrees that during the Term and at all times thereafter, Consultant shall not, directly or indirectly, communicate in any manner with any member of the press or media concerning the Company, its affiliates, current or former officers, directors, or Consultants except as permitted by law and/or Company policy.

B.    Partial Invalidity. In the event any court of competent jurisdiction holds any provision of this Agreement to be invalid or unenforceable, such invalid or unenforceable portion(s) shall be limited or excluded from this Agreement to the minimum extent required, and the remaining provisions shall not be affected or invalidated and shall remain in full force and effect.

C.    Reformation. Consultant agrees that in the event any of the covenants contained in this Agreement shall be held by any court to be effective in any particular area or jurisdiction only if said covenant is modified to limit its duration or scope, then the court shall have such authority to so reform the covenant and the parties hereto shall consider such covenant(s) and/or other provisions to be amended and modified with respect to that particular area or jurisdiction so as to comply with the order of any such court and, as to all other jurisdictions, the covenants contained herein shall remain in full force and effect as originally written.
 
D.    Entire Agreement. This Agreement is the entire agreement between the parties with respect to the subject matter hereof, and fully supersedes any and all prior agreements, understandings, or representations between the parties, whether oral or written, pertaining to the subject matter of this Agreement (including, for the avoidance of doubt, any term sheets discussed, negotiated or signed by and between the parties). Consultant represents and acknowledges that in executing this Agreement, Consultant does not rely, and has not relied, upon any representation(s) by the Company or its agents except as expressly contained in this Agreement. Consultant agrees that Consultant has used Consultant’s own judgment in executing this Agreement. This Agreement may not be amended unless it is in writing and signed by Consultant and the Company. This Agreement shall be binding upon the parties, their heirs, legal representatives, successors and assigns.

E.    Controlling Law. Any dispute in the meaning, effect, or validity of this Agreement and/or any dispute arising out of Consultant’s relationship with the Company shall be resolved in accordance with the laws of the State of Texas without regard to the conflict of laws provisions thereof. Venue of any litigation arising from this Agreement or Consultant’s relationship with the Company shall be in a state district court of competent jurisdiction in Harris County, Texas, or the United States District Court for the Southern District of Texas, Houston Division. Consultant consents to personal jurisdiction of the state district courts of Harris County, Texas and to the United States District Court for the Southern District of Texas, Houston Division, and agrees that Consultant shall not challenge personal jurisdiction in such courts. Consultant waives any objection that Consultant may now or hereafter have to the venue or jurisdiction of any proceeding in such courts or that any such proceeding was brought in an inconvenient forum (and agrees not to plead or claim the same).






F.    Voluntary Agreement. Consultant acknowledges that Consultant has had an opportunity to consult with an attorney or other counselor concerning the meaning, import, and legal significance of this Agreement, and Consultant has read this Agreement, as signified by Consultant’s signature hereto, and Consultant has either waived the advice of counsel or is voluntarily executing this Agreement after advice of counsel for the purposes and consideration herein expressed.

G.    Limitations on Assignment. In entering into this Agreement, the Company is relying on the unique services of Consultant; services from another company or contractor will not be an acceptable substitute. Except as provided in this Agreement, Consultant may not assign this Agreement or any of the rights or obligations set forth in this Agreement without the explicit written consent of the Company. Any attempted assignment by Consultant in violation of this paragraph shall be void. Whether with or without Consultant’s consent, the Company may assign this Agreement in whole or part to any of its subsidiaries or any successor.

H.    Headings. The headings contained in this Agreement are for reference purposes only and will not affect in any way the meaning or interpretation of this Agreement.

I.    Counterparts. This Agreement and amendments to it will be in writing and may be executed in counterparts. Each counterpart will be deemed an original, but both counterparts together will constitute one and the same instrument.
    
J.    Ambiguities.    Any rule of construction to the effect that ambiguities shall be resolved against the drafting party shall not apply to the interpretation of this Agreement.

K.    Miscellaneous.    In this Agreement, (i) “hereto,” “herein,” and similar terms are references to this Agreement as a whole; (ii) “Section” refers to a section of this Agreement, unless otherwise indicated; (iii) the singular includes the plural and vice versa, and each gender includes each of the others; (iv) the use herein of the word “including,” when following any general statement, term or matter, shall not be construed to limit such statement, term or matter to the specific items or matters set forth immediately following such word or to similar items or matters, whether or not non-limiting language (such as “without limitation,” or “but not limited to,” or words of similar import) is used with references thereto, but rather shall be deemed to refer to all other items and matters, that reasonably could fall within the broadest possible scope of such general statement, term or matter; and (v) “or” means and / or.

L.    Notice.    All notices required or permitted to be given hereunder shall be in writing and shall be valid and sufficient if dispatched (i) by hand delivery, (ii) by facsimile transceiver, with confirming letter mailed promptly thereafter by first class mail, postage prepaid, (iii) by overnight express courier or (iv) by certified mail, postage prepaid, return receipt requested, deposited in any post office in the United States, in any case, addressed to the addresses set forth on the signature page of this Agreement, or such other addresses as may be provided from time to time in the manner set forth above. When sent by facsimile, notices shall be considered to have been received at the beginning of recipient's next business day following their confirmed transmission; otherwise, notices shall be considered to have been received only upon delivery or attempted delivery during normal business hours.






The signatures below indicate that the Parties have read, understand and will comply with this Agreement, which is effective as of the Effective Date and has been executed as of December 31, 2019.

Patrick Carey Lowe

Signature:    /s/ Patrick Carey Lowe                             
Printed Name:    Patrick Carey Lowe

Address:



ENSCO Incorporated

Signature:    /s/ Kristin Larsen

Name: Kristin Larsen

Title     Vice President and Secretary - ENSCO Incorporated     

Address:    5847 San Felipe, Suite 3300
Houston, Texas 77057             
Attention: General Counsel                     








EXHIBIT 1
LIST OF PRIOR PROPRIETARY INFORMATION


None.








Exhibit 10.61

SEVERANCE AGREEMENT
DATED: December 31, 2019
This Agreement is entered into between:
(1)
Ensco Global Resources Limited, (registered in England under no. 07098531) whose registered office is at 7 Albemarle Street, London, England, W1S 4HQ (“Company"); and
(2)
Patrick Carey Lowe (the "Executive").
Whereas:
(A)
The Parties acknowledge that the Executive has been employed by the Company since 18 August 2008.
(B)
In order to achieve certainty and finality, it is the intention of the Executive and the Company in entering into this Agreement that it shall operate to terminate the relationship between them and, in consideration of the settlement set out herein, provide a full and absolute and irrevocable release by the Executive of all current and future claims in any jurisdiction in connection with his employment whether or not he has knowledge of them, whether or not they are in the contemplation of the Parties and whether or not they exist in fact or law, as at the date of this Agreement.
(C)
This Agreement contains confidentiality provisions in Section B of Annex A, which are clear and specific as regards what the Executive is entitled to disclose, in full compliance with all legal and regulatory requirements.
By signing this Agreement, the Executive and the Company hereby agree as follows:
1.
Definitions and Interpretation
1.1
In this Agreement:
the "Adviser"
means Adrian Hoggarth;
"Affiliate"
means any company which is for the time being a subsidiary, subsidiary undertaking or holding company of Valaris plc or the Company, or a subsidiary or subsidiary undertaking of any such holding company (the terms "subsidiary" and "holding company" being defined as in section 1159 of the Companies Act 2006 and "subsidiary undertaking" being defined as in section 1162 of that Act);
Valaris plc
means Valaris plc, a company registered in England under company number 07023598; and
Parties
means both the Company and the Executive, and “Party” shall mean any one of them.
1.2 References to any statute or any statutory provision shall, unless the context otherwise requires, be construed as including any subsequent or amended statute or any corresponding provision of such new or amended statute.


2.
Termination of Employment.





2.1. The Executive’s employment with the Company will terminate on 31 December 2019 (the “Termination Date”).
2.2. This Agreement is deemed as providing notice between the Company and the Executive. The Company and the Executive agree that the totality of the arrangements set out in this Agreement provide the Executive with reasonable notice.
2.3. The salary and benefits provided to the Executive under his normal terms of employment will be paid by the Company in the normal way up to and including the Termination Date, but thereafter will cease.
2.4.The Executive agrees to waive payment in lieu of holiday entitlement accrued but untaken as at the Termination Date (if any).
2.5. The Company acknowledges the Executive’s letter marked for the attention of Shareholders and Board of Directors dated 22 November 2019 in respect of his resignation as Director and/or Officer of the companies and positions listed therein as Exhibit A, effective as of 30 November 2019. The Executive confirms that he will execute such further deeds, forms and documents as the Company or any relevant Affiliate may request to ensure completion of such resignations and any other formal resignations/removals, including in respect of any trusteeship or nominee shareholdings.
2.6. The Company will procure that, for a period of six years after the Termination Date, the Executive will be covered by directors’ and officers’ liability insurance cover in respect of the Executive’s position as a director or officer of the Company and any Affiliate, if and to the extent that existing or former directors of the Company or relevant Affiliate are so covered, subject always to the terms of the applicable scheme as in force from time to time. The Company gives no warranty as to the continued existence or extent of such cover.
3. Severance Benefits and Legal Costs
3.1. Subject to the Executive’s compliance with all the terms and warranties of this Agreement, the Company shall provide the Executive with the cash payments and benefits set out in Section A of Annex A at the times set out therein. All payments shall be made subject to any necessary deductions for income tax and social security contributions and any other deductions required or authorised to be made by virtue of a statutory provision.
3.2. On the commencement of any proceedings by the Executive against the Company or any Affiliate or any other material breach of this Agreement by the Executive, the Company may, in its absolute discretion, require all or part of the Cash Severance (as defined in Section A-1 of Annex A) to be repaid if and to the extent that the Company incurs any liabilities, losses, damages, costs or expenses as a result of or in connection with such proceedings or breach. The Company may commence proceedings to recover such an amount as a debt owing from the Executive. The Executive agrees that this repayment provision is intended to be a genuine pre-estimate of the loss which may be suffered by the Company or any Affiliate in such circumstances, and in no way constitutes a penalty.
3.3.
3.3.1 The Company shall maintain continued group health plan coverage following the Termination Date under any of Valaris corporate’s group health plans that covered the Executive immediately before the Termination Date which are subject to the Consolidated Omnibus Budget Reconciliation Act of 1985, as amended (“COBRA”) (as codified in Code Section 4980B and Part 6 of Subtitle B of Title I of ERISA), for the Executive and his eligible spouse and other eligible dependents (together, “Dependents”), for a period of one (1) year following the Termination Date. During this period, the Executive shall be responsible for paying the cost associated with COBRA coverage at the same rate that the Executive paid for coverage under such group health plans immediately prior to the Termination Date. Following the one (1) year anniversary of the Termination Date, the Executive shall be responsible for the full cost associated with COBRA coverage.

3.3.2 After the Termination Date, the Executive, and his Dependents, if any, must first elect and maintain any COBRA continuation coverage under the group health plan that they are entitled to receive under the





terms of such plan and COBRA. In all respects, the Executive and his Dependents shall be treated the same as other COBRA qualified beneficiaries under the terms of such plan and the requirements of COBRA during the period while COBRA coverage remains in effect.
  
3.3.3 The Company’s obligation to provide the COBRA coverage shall be terminated if the Executive becomes eligible for group medical coverage provided by another employer. The Executive covenants to give prompt notice to the Company if he becomes eligible for group medical coverage offered by another employer during the period in which he and his Dependents are covered by COBRA.

3.3.4 The provision of benefits under this Section shall only apply if and to the extent that such benefits are provided to employees of the Company for that period, subject always to the terms of the applicable scheme and of any related policy of insurance as in force from time to time. The Company gives no warranty as to the continued existence or extent of such benefits.
3.4 The Company will pay the reasonable costs of the Adviser, being costs incurred by the Executive exclusively in connection with advice as to the terms and effect of this Agreement and, in particular, (a) its effect on his ability to pursue a claim before an Employment Tribunal or other court following its signing and (b) the nature and limitations of the confidentiality provisions contained in the Agreement, subject to its receipt of an invoice addressed to the Executive and marked payable by the Company in respect of those costs and subject to a maximum (excluding VAT but including all disbursements) of GBP £1,000.
4. Employment Reference. The Company shall, within seven (7) days of receipt of a request from a prospective employer or employment agency, provide a factual employment reference confirming the identity of the positions held by the Executive and the dates of the Executive’s employment with the Company. This Section is subject to any legal obligations the Company may have in respect of the contents of a written reference, and to the proviso that the Company will cease to be obliged to provide a reference, whether written or oral, in the agreed terms if, after the signing of this Agreement, new facts come to the Company’s attention which suggest that the agreed reference would be inaccurate or misleading. The Company also reserves the right to make such disclosures as are required by law or regulatory requirements. While any reference will be given in good faith, neither the Company, any Affiliate nor their directors, officers or employees shall be liable for any errors, omissions or inaccuracies in the information contained in the reference, or any loss or damage caused by it.
5. Taxation
5.1 The Company will pay the Cash Severance payable under Section A-1 of Annex A less all required deductions for income tax and social security contributions.
5.2 Any further tax or social security contributions which may be payable in respect of any payment or benefit provided under this Agreement will be for the Executive's own account and the Executive agrees with the Company that, to the extent that the Company or any Affiliate is obliged to make any payment of, or in respect of, tax or social security contributions or of any fine, penalty or interest ("Taxes") in respect of any payment or benefit provided under this Agreement, the Executive will promptly indemnify the Company or the relevant Affiliate on an after-tax basis in full for any such Taxes (except any fine, penalty or interest charged solely by reason of any fault or delay by the Company or the relevant Affiliate in dealing with an assessment for tax by any relevant authority). The Company will endeavour to notify the Executive at his last known address of any claim or demand that it has received in respect of any such Taxes, and afford the Executive a reasonable opportunity to, and provide the Executive with reasonable access to any documentation the Executive may reasonably require to, challenge or dispute such a claim or demand at his own expense.
6. Certain Continuing Obligations. The Executive acknowledges and agrees that the post-termination restrictive covenants and obligations that apply to the Executive as set forth in Section B of Annex A shall survive termination of the employment relationship and the execution of this Agreement, and the Executive shall continue to fully honor his post-employment obligations.





7. Full and Final Settlement. The Executive expressly agrees that the terms of this Agreement are in full and final settlement of:
(a)
all and any claims, costs, expenses or rights of action of any kind whatsoever or howsoever arising (whether statutory, contractual, at common law or otherwise) whether known or unknown to the Parties, whether or not existing in fact or in law at the time of this Agreement and whether or not they are or could be in the contemplation of the Parties at the time of this Agreement (and whether arising in the United Kingdom or in any other country in the world) that he may have now or in the future against the Company or any Affiliate or any of their officers, shareholders or employees relating to or arising directly or indirectly out of or in connection with his employment prior to the Termination Date, the termination of his employment with the Company or any other matter whatsoever outstanding on the Termination Date, including but not limited to any claim relating to or arising out of any directorships or other offices with the Company or any Affiliate or their termination (the "Specified Matters"); and
(b)
any claim which the Executive may otherwise have for: breach of contract (including wrongful dismissal); unfair dismissal; detrimental treatment or dismissal relating to a protected disclosure; redundancy; unlawful deduction from wages; holiday pay; equal pay; unlawful discrimination, harassment or victimisation on grounds of age, disability (including discrimination arising from disability and failure to make reasonable adjustments), gender reassignment, marriage and civil partnership, race, religion or belief, sex or sexual orientation; personal injury; and any breach of (a) the right to be accompanied under the Employment Relations Act 1999; (b) the Employment Rights Act 1996 (or any regulations made under that Act); (c) the Trade Union and Labour Relations (Consolidation) Act 1992; (d) the Working Time Regulations 1998; (e) the National Minimum Wage Act 1998; (f) the Part-Time Workers (Prevention of Less Favourable Treatment) Regulations 2000; (g) the Fixed-Term Employees (Prevention of Less Favourable Treatment) Regulations 2002; (h) the Information and Consultation of Employees Regulations 2004; (i) the Transnational Information and Consultation of Employees Regulations 1999; (j) the Protection from Harassment Act 1997; (k) the Data Protection Act 2018; (l) the Occupational and Personal Pension Scheme (Consultation by Employers and Miscellaneous Amendment) Regulations 2006; (m) the Pensions Act 2008; and (n) the General Data Protection Regulation (Regulation (EU) 2016/679), as regards a claim for damages for any breach which occurred prior to the date of this Agreement, and any legislation, order or regulation implementing such regulation (the "Specified Claims").
(c)
The waiver in Section 7 shall not extend to: (a) any claims by the Executive to enforce the terms of this Agreement; or (b) any claim for any latent personal injury attributable to the Executive’s employment with the Company of which the Executive is unaware, and of which he could not reasonably be expected to be aware, as at the date of this Agreement.
8. Warranties
8.1 The Executive warrants, undertakes and represents to the Company that:
(a)
having taken independent legal advice from the Adviser, he has notified the Company in writing of all and any actual or potential claims (whether at the date of this Agreement or in the future) he may have against the Company or any Affiliate or any of their employees, officers or shareholders and he has no other complaints whatsoever against the Company in relation to the Specified Matters including, without limitation, the Specified Claims;
(b)
he shall not continue, institute or commence any claims, actions or proceedings before any court or Employment Tribunal whatsoever arising out of or in connection with his employment with the Company or its termination or otherwise, and he undertakes that neither he nor anyone acting on his behalf will present or issue such a claim; and
(c)
as at the date of this Agreement he has not committed any act or made any omission which might amount to a repudiatory breach of his terms and conditions of employment (or which would be a breach of this Agreement,





if it happened after the date of this Agreement) and that there are no circumstances which would entitle the Company to terminate his employment without notice.
8.2 The Executive acknowledges that the Company has entered into this Agreement in reliance on the warranties, undertakings and representations above.
9. Compliance with Statutory Requirements
9.1 The Executive confirms that he has taken independent legal advice as to the terms and effect of this Agreement from the Adviser, who is a solicitor of the Senior Courts of England and Wales holding a current practising certificate and in respect of whom there is currently in force a policy of insurance covering the risk of a claim in relation to the advice given to the Executive. The Executive understands that by entering into this Agreement he will not be able to bring or pursue any claim in any court or Employment Tribunal against the Company or any Affiliate arising from his employment with the Company or its termination including, without limitation, the Specified Claims. The Executive also confirms that he has received independent legal advice from the Adviser on the nature and limitations of the confidentiality provisions in Section B of Annex A.
9.2 The Parties agree that the conditions regulating settlement agreements under the following provisions have been satisfied:
(a)
section 203(3) of the Employment Rights Act 1996;
(b)
section 147(3) of the Equality Act 2010;
(c)
section 14 of the Employment Relations Act 1999;
(d)
section 288(2B) of the Trade Union and Labour Relations (Consolidation) Act 1992;
(e)
regulation 35(3) of the Working Time Regulations 1998;
(f)
section 49(4) of the National Minimum Wage Act 1998;
(g)
regulation 9 of the Part Time Workers (Prevention of Less Favourable Treatment) Regulations 2000;
(h)
regulation 10 of the Fixed Term Employees (Prevention of Less Favourable Treatment) Regulations 2002;
(i)
regulations 39 and 40 of the Information and Consultation of Employees Regulations 2004;
(j)
regulations 40 and 41 of the Transnational Information and Consultation of Employees Regulations 1999;
(k)
paragraphs 12 and 13 of the schedule to the Occupational and Personal Pension Scheme (Consultation by Employers and Miscellaneous Amendment) Regulations 2006; and
(l)
section 58(5) of the Pensions Act 2008.
10. Co-Operation. After the Termination Date, the Executive agrees to provide the Company and any Affiliate with such reasonable assistance as may be required, regarding matters of which he has knowledge and/or experience, with respect to and in the conduct of any litigation or investigation arising from or in relation to events that occurred during the Executive’s employment with the Company (whether such litigation or investigation is then pending or subsequently initiated) involving the Company or any Affiliate, including (but not limited to) providing testimony and preparing to provide testimony if so requested by the Company or relevant Affiliate. The Executive’s reasonable expenses properly incurred and evidenced and incurred wholly in connection with the performance of his obligations under this Section will be reimbursed, and the Executive will receive a reasonable fee (in an amount determined by the Company or relevant Affiliate) in consideration of his time in complying with this Section.






ANNEX A

A.
Severance Benefits. Without prejudice to Section 3 of this Agreement, the Executive shall receive the following Severance Benefits:
1.
Cash Severance. By way of compensation for the termination of his employment but without any admission of liability, the Company will make a payment to the Executive of USD $2,300,000, subject to any necessary deductions for income tax and social security contributions, by electronic transfer to the account nominated by the Executive for payroll purposes, no later than thirty (30) days after the later of:
(i)
the Termination Date; and
(ii)
receipt by the Company’s General Counsel of a copy of this Agreement (including this Annex A) signed by the Executive, together with the Adviser's certificate in Appendix 1 to this Agreement signed by the Adviser.
2.
Cash Bonus. A cash amount, payable on the date in March 2020 when such bonus amounts relating to the 2019 calendar year are otherwise payable to similarly situated employees of the Company, equal to the Executive’s bonus under the Cash Incentive Plan (“ECIP”) based on the actual achievement of applicable performance metrics. Any bonus paid shall be paid subject to any necessary deductions for income tax and social security contributions and the Executive waives any further rights to any bonus payment under the ECIP. For the avoidance of doubt, the Executive shall not be entitled to bonus relating to any calendar year after the 2019 calendar year.
The Executive hereby agrees and acknowledges that all equity-based awards (whether to be settled in cash or shares) held by the Executive under any equity or long-term incentive plans of the Company or an Affiliate - including without limitation all Restricted Share Awards, Restricted Share Units and Performance Unit Awards - will be forfeit on the Termination Date. The Executive also hereby waives all rights to any further payments or awards under such plans.
3.
Tax Assistance: The Company shall pay for the cost associated with the preparation of the Executive’s tax returns and the resolution of any tax issues that may result from payment received as a result of the Executive’s employment with the Company in the United Kingdom in the same manner and to the same extent that the Company provides this benefit to other executives of the Company. It is the Executive’s responsibility to file returns and provide any required documentation on a timely basis to comply with U.S. expatriate tax laws as well as the tax laws of the United Kingdom. The Company shall neither be responsible nor reimburse the Executive for any penalties or interest assessed to or incurred by the Executive resulting from or attributable to the Executive’s failure to timely file any return or timely provide any required information or documentation. Notwithstanding anything herein to the contrary, the third party tax services provided in this Section will only apply with respect to taxes due on payments and other compensation the Executive has received and will receive from the Company and will apply to: (i) any tax periods in which the Executive has received or will receive any such payments or other compensation from the Company and (ii) any tax periods in which the Executive is subject to taxation in the United Kingdom in respect of his employment with the Company.
B.
Restrictive Covenants
1.
In consideration for payment of USD $56,000 (subject to deduction of income tax and National Insurance contributions) (“RC Payment”), the Executive represents to, and covenants with or in favor of the Company and any Affiliate, that:
i.
the Executive will comply with all post-termination restrictive agreements, policies or covenants that apply to, or cover, the Executive, including, without limitation, those regarding Confidential





Information (as defined below), return of Company property and non-disparagement, as set forth in Sections B-2, B-3 and B-4 hereof;
ii.
the Executive will comply with all of the Company’s policies, standards and procedures covering the Executive as an employee, officer or director of the Company or any Affiliate; and
iii.
the Executive will comply with Section C of this Annex A.
The covenants undertaken by the Executive in this Section are undertaken to the Company for itself and as agent for all Affiliates, and shall apply whether he acts directly or indirectly.
The Executive hereby agrees that he will, at the request and expense of the Company, enter into a direct agreement or undertaking with any Affiliate whereby he will accept restrictions and provisions corresponding to the restrictions and provisions in this Section (or such of them as may be appropriate in the circumstances) in relation to such activities and such area and for such a period as such Affiliate may reasonably require for the protection of its legitimate business interests.
The Company will make a payment to the Executive of the RC Payment by electronic transfer to the account nominated by the Executive for payroll purposes, no later than thirty (30) days after the later of:
(i)    the Termination Date; and
(ii)
receipt by the Company’s General Counsel of a copy of this Agreement (including this Annex A) signed by the Executive, together with the Adviser's certificate in Appendix 1 to this Agreement signed by the Adviser.
2.
Confidentiality
(a)
During the course of the Executive’s employment with the Company, the Company has or will (1) disclose or entrust to the Executive, and provide the Executive with access to, Confidential Information, (2) place the Executive in a position to develop business goodwill belonging to the Company, and (3) disclose or entrust to the Executive business opportunities to be developed for the Company.
(b)
The Executive acknowledges that Confidential Information has been and will be developed or acquired by the Company through the expenditure of substantial time, effort and money and provides the Company with an advantage over competitors who do not know or use the Confidential Information. The Executive further acknowledges and agrees that the nature of the Confidential Information obtained during his employment would make it difficult, if not impossible, for the Executive to perform in a similar capacity for a business competitive with the Company without disclosing or utilising Confidential Information.
(c)
During and following the Executive’s employment by the Company, the Executive shall hold in confidence and not directly or indirectly disclose, use, copy or make lists of any Confidential Information, except to the extent necessary to carry out his duties on behalf of the Company. Subject to Section B-6 of this Annex A below, and only insofar as the Executive is permitted to do so (if such compulsion has been requested by any regulatory or governmental authority or body), the Executive agrees to give the Company notice of any and all attempts to compel disclosure of any Confidential Information within one (1) business day of being informed that such disclosure is being, or will be, compelled. Such written notice shall include a description of the Confidential Information to be disclosed, the court, government agency, or other forum through which the disclosure is sought, and the date by which the Confidential Information is to be disclosed, and shall contain a copy of the subpoena, order or other process used to compel disclosure. For the avoidance of doubt, the provisions of this subsection shall not apply to (a) any disclosure or use authorised by the Company or required by applicable law and (b) any information that is or becomes generally available to the public (other than as a result of the Executive’s unauthorised disclosure).





(d)
This confidentiality covenant shall be in addition to, and not limit or restrict in any way, any other confidentiality agreement or other post-employment covenant between the Executive and the Company.
(e)
Confidential Information” means information (whether or not recorded in documentary form, or stored on any magnetic or optical disk or memory) relating to the business, products, affairs and finances of the Company or any Affiliate for the time being confidential to the Company or the relevant Affiliate, and trade secrets including, without limitation, technical data and know-how relating to the business of the Company or any Affiliate or any of their business contacts, including in particular (by way of illustration only and without limitation): (i) information relating to the business of exploring, acquiring, developing, exploiting and disposing of oil and natural gas resources (regardless of when conceived, made, developed or acquired); (ii) information relating to the business or prospective business, current or projected plans or internal affairs of the Company or any Affiliate; (iii) information relating to the current or prospective marketing or sales of any products or services of the Company or any Affiliate, including non-public lists of customers' and suppliers' names, addresses and contacts; sales targets and statistics; market share and pricing information; marketing surveys; research and reports; non-public advertising and promotional material; strategies; and financial and sales data; (iv) information relating to any actual or prospective business strategies of the Company or any Affiliate; (v) information relating to any actual acquisitions, investments or corporate opportunities or prospective acquisition, investment targets or corporate opportunity; (vi) know-how, trade secrets, unpublished information relating to the Company’s or any Affiliate’s intellectual property and to the creation, production or supply of any products or services of the Company or any Affiliate; (vii) information to which the Company or any Affiliate owes an obligation of confidence to a third party (including, without limitation, customers, clients, suppliers, partners, joint venturers and professional advisors of the Company or any Affiliate); and (viii) other commercial, financial or technical information relating to the business or prospective business of the Company or any Affiliate, or to any past, current or prospective client, customer, supplier, licensee, officer or employee, agent of the Company or any Affiliate, or any member or person interested in the share capital or assets of the Company or any Affiliate, and any other person to whom the Company or any Affiliate may provide or from whom they may receive information which is confidential or commercially sensitive and is not in the public domain (whether marked confidential or not).
3.
The Executive confirms that all writings, records, and other documents and things comprising, containing, describing, discussing, explaining, or evidencing any Confidential Information, and all equipment, computers, mobile phones, components, manuals, parts, keys, tools, and the like, and any other property in the Executive’s custody, possession or control that have been obtained by, prepared by, or provided to, the Executive by the Company or any Affiliate in the course or scope of his employment with the Company (or any Affiliate) shall be and remains the exclusive property of the Company (or any Affiliate, as applicable), shall not be copied and/or removed from the premises of the Company or any Affiliate, except in pursuit of the business of the Company or any Affiliate, and shall be delivered to the Company or any Affiliate, as applicable, without the Executive retaining any copies or electronic versions, by the Termination Date.
4.
To the extent permissible by law or regulatory requirements and to the extent such information is not in the public domain, the Executive and the Company agree to keep the circumstances leading to the termination of the Executive’s employment and the terms (but not the existence) of this Agreement entirely confidential.
5.
The Executive shall refrain from, either orally or in writing, any criticisms or disparaging comments about the Company, any Affiliate or any of their directors, officers or employees, or in any way relating to his employment or separation from employment with the Company. The Executive further agrees that he will not take any action which could reasonably be expected to damage the reputation or be detrimental to or otherwise critical of the Company or any Affiliate or any of their directors, officers or employees. The Company shall, with effect from the Termination Date, use reasonable endeavors to instruct the executive officers and/or directors of the Company to refrain (subject to any legal or regulatory requirements) from any criticisms or





disparaging comments (whether orally or in writing) about the Executive or in any way relating to his employment or separation from employment with the Company (or any Affiliate).
6.
The restrictions contained in this Section B of this Annex A will not apply to the Executive:
a.
making a disclosure in relation to which he receives specific prior consent from the Company in accordance with Section B-7 of this Annex A such consent not to be unreasonably refused or delayed;
b.
making a protected disclosure within the meaning of Part IVA of the Employment Rights Act 1996 (commonly known as “whistleblowing”). For the avoidance of doubt and as a non-exhaustive summary only, a disclosure is protected for these purposes if:
i.
the Executive has a reasonable belief that the disclosure is made in the public interest and the relevant information disclosed indicates there is, has been, or is likely to be, a criminal offence, a breach of a legal obligation, a miscarriage of justice, danger to the health and safety of an individual or damage to the environment - or that any such matter has been or is likely to be deliberately concealed; and
ii.
the disclosure is made to an appropriate body, including but not limited to a regulator or legal adviser;
c.     making a disclosure to the police;
d.     reporting an offence to a law enforcement agency;
e.    reporting a regulatory breach to a regulator;
f.    co-operating with a criminal investigation or prosecution;
g.    complying with an order of a court or tribunal of competent jurisdiction;
h.
disclosing information for the purpose of seeking legal, medical or professional advice (provided that the Executive uses reasonable endeavours to ensure that those professional advisers are subject to a duty of confidentiality as regards that disclosure);
i.    disclosing information to the relevant tax authorities in respect of the Executive’s personal tax affairs;
j.    making a relevant pay disclosure under section 77 of the Equality Act 2010;
k.
disclosing information which is in or has come into the public domain other than through an unauthorised disclosure by the Executive;
l.
in respect of the facts leading up to termination or the terms of this Agreement only, disclosing information to the Executive’s spouse, civil partner or partner (provided that the Executive uses reasonable endeavours to ensure that they agree to keep the information confidential);
m.
in respect of the facts leading up to termination or the terms of this Agreement only, disclosing information to the Executive’s recruitment consultant or a prospective employer to the extent necessary to discuss his employment history; or
n.    making any disclosures which are required by law or regulatory requirements.
7.
If the Executive has any queries in relation to Section B-6 of this Annex A, or in order to seek consent for the purposes of Section B-6(a), these should be directed to the General Counsel of the Company.





C.
Intellectual Property
1.
The Parties are aware that the Executive may create or have created or make or made Company Works, Company Inventions and Company IPR, during the course of his employment and duties with the Company and that all Company Works, Company Inventions and Company IPR were vested in and owned by the Company immediately upon their creation.
2.
To the extent that such rights did not or do not vest immediately in the Company:
a.
the Executive hereby agrees to assign to the Company all of the Executive’s right, title and interest in the Company Works, Company Inventions and Company IPR free of charge subject to the Patents Act 1977; and
b.
the Executive hereby assigns to the Company all future copyright, database rights and rights in designs in the Company Works and Company Inventions.
3.
The Executive shall promptly disclose to the Company full details of any Company Works, Company Inventions and Company IPR and shall render all possible assistance to the Company both in obtaining and in maintaining such Company IPR and shall forthwith and from time to time, at the request and expense of the Company, do all things and execute all documents necessary or desirable to give effect to the provisions of this Section C of Annex A.
4.
The Executive shall not, either before or after the Termination Date (unless the same shall have become public knowledge), make public or disclose any Company Works or Company Inventions or give any information in respect of it except to the Company or as the Company may direct.
5.
The Executive hereby irrevocably and unconditionally waives, in favour of the Company, its licensees and successors in title any and all moral rights conferred on the Executive by Chapter IV of Part I of the Copyright, Designs and Patents Act 1988 in relation to all Company Works (existing or future).
6.
In this Section C, the following terms have the following meanings:
“Company Invention”
means any invention, development, discovery, idea, improvement, process or innovation whether patentable or capable of registration or not and whether or not recorded in any medium, made wholly or partially by the Executive alone or with others (except only those which are made by the Executive wholly outside the course of his employment);
“Company IPR”
means all Intellectual Property Rights created by the Executive alone or with others (except only those Intellectual Property Rights which are created by the Executive wholly outside the course of his employment) including but not limited to all Intellectual Property Rights subsisting from time to time in any Company Invention or Company Works;






“Company Works”
means all works and materials including but not limited to documents, designs, drawings, photos, graphics, papers, records, reports, software, typographical arrangements get-up, and trade names, authored, originated, conceived, written or made wholly or partially by the Executive alone or with others (except only those which are authored, originated, conceived, written or made by the Executive wholly outside the course of his employment); and
“Intellectual Property Rights”
means any and all intellectual property rights including without limitation patents, know-how, trade marks, rights in designs, trade or business names, copyrights, database rights and topography rights (whether or not any of these is registered and including applications for registration of any such thing) and all rights or forms of protection of a similar nature or having equivalent or similar effect to any of these which may subsist anywhere in the world.

D.
Miscellaneous.
1.
This Agreement may be executed in any number of counterparts, and by the Parties on separate counterparts, but shall not be effective until each Party has executed at least one counterpart.
2.
Each counterpart shall constitute an original of this Agreement, but all the counterparts shall together constitute but one and the same instrument.
3.
This Agreement may be executed by faxed or emailed copies.
4.
Notwithstanding that this Agreement is marked "without prejudice" and "subject to contract" it shall when signed by all Parties become binding and open.
5.
This Agreement (including for the avoidance of doubt this Annex A) shall be governed by and construed under English law and each of the Parties hereby irrevocably agrees for the exclusive benefit of the Company that the Courts of England are to have exclusive jurisdiction to settle any disputes which may arise out of or in connection with this Agreement.
6.
This Agreement (including for the avoidance of doubt this Annex A) may be amended or modified only by a written instrument identified as an amendment hereto that is executed by both Parties.
7.
This Agreement (including for the avoidance of doubt this Annex A) sets forth the entire agreement of the Parties and fully supersedes and replaces any and all prior agreements, promises, representations, or understandings, written or oral, between the Company (and any Affiliate) and the Executive that relates to the subject matter of this Agreement, other than any terms of employment of the Executive that are expressed to survive termination and have not been terminated by this Agreement. The Executive acknowledges that in executing this Agreement, the Executive does not rely, and has not relied, upon any oral or written representation, promise or inducement by the Company and/or any Affiliate or any of their officers, shareholders or employees, except as expressly contained in this Agreement.
8.
A Party’s waiver of any breach or violation of any provision of this Agreement shall not operate as, or be construed to be, a waiver of any later breach of the same or any other provision hereof by such Party.
9.
Should any provision of this Agreement (including for the avoidance of doubt this Annex A) be declared or be determined by any court of competent jurisdiction to be illegal, invalid or unenforceable, all remaining provisions of this Agreement shall otherwise remain in full force and effect and be construed as if such illegal, invalid, or unenforceable provision has not been included herein.
10.
Wherever appropriate to the intention of the Parties, the respective rights and obligations of the Parties hereunder shall survive any termination or expiration of this Agreement.





11.
In accordance with the Contracts (Rights of Third Parties) Act 1999, only the Executive, the Company and any Affiliate and any director, officer, employee or shareholder thereof may enforce this Agreement. The consent of only the Parties is required for the variation or termination of this Agreement, even if that variation or termination affects the benefits conferred on any third party.





SIGNED ..............................................
for and on behalf of
Ensco Global Resources Limited






SIGNED ..............................................
Patrick Carey Lowe






APPENDIX 1
Adviser's Certificate
1.
I am a solicitor of the Senior Courts of England and Wales holding a current practising certificate.
2.
I have advised Patrick Carey Lowe of the terms and effect of this Agreement and, in particular:
a) its effect on his ability to pursue a claim before an Employment Tribunal or other court following its signing; and
b) the nature and limitations of the confidentiality provisions contained in the Agreement.
3.
I am not acting (and have not acted) in relation to this matter or any other matter for the Company or any Affiliate.
4.
There is currently in force a policy of insurance covering the risk of a claim by Patrick Carey Lowe in respect of loss arising in consequence of the advice I have given.

Signed ............................................................
Adrian Hoggarth
Jurit LLP

Dated: ……………………….. 2019







Exhibit 10.77

VALARIS EXECUTIVE SEVERANCE PLAN
INTRODUCTION
The purpose of this Valaris Executive Severance Plan is to enable the Employer to offer certain payments and benefits to Eligible Individuals if their employment with the Employer is terminated by the Employer without Cause (and not on account of death or Disability).
ARTICLE I
DEFINITIONS
For purposes of the Plan, capitalized terms and phrases used herein shall have the meanings ascribed in this Article I.
1.1    Accrued Obligations means (i) all earned but unpaid Base Pay through the date of termination prorated for any partial period of employment, payable in accordance with customary payroll practices and the requirements of applicable law; (ii) any benefits to which such individual has a vested entitlement as of the date of termination, payable in accordance with the terms of any applicable benefit plan or as otherwise required by law; (iii) any accrued but unused vacation, payable in a lump sum with the individual’s final paycheck or as otherwise required by law; and (iv) payment of any approved but not yet reimbursed business expenses incurred prior to the date of termination, payable in accordance with applicable policies of the Company and its Affiliates.
1.2    Affiliate shall have the meaning set forth in Rule 12b-2 promulgated under Section 12 of the Exchange Act.
1.3    Base Pay means a Participant’s annual base compensation rate for services paid by the Employer to the Participant at the time immediately prior to the Participant’s termination of employment, as reflected in the Employer’s payroll records. Base Pay shall not include commissions, bonuses, overtime pay, incentive compensation or benefits paid under any retirement plan, any group medical, dental or other welfare benefit plan, non-cash compensation, or any other additional compensation.
1.4    Board means the Board of Directors of Valaris plc, a public limited company incorporated under the laws of England and Wales, or any successor thereto.
1.5    Cause means any of the following: (a) the willful and continued failure of a Participant to perform substantially the Participant’s duties and obligations (other than any such failure resulting from bodily injury or disease or any other incapacity due to mental or physical illness), (b) gross misconduct by the Participant, (c) the willful and material breach by the Participant of any policies of the Company or its Affiliates or the Valaris Code of Conduct, or (d) the conviction of the Participant by a court of competent jurisdiction, from which conviction no further appeal can be taken, of a crime punishable by imprisonment.
1.6    Change in Control means the occurrence of any of the following events: (a) a change in the ownership of Valaris plc, which occurs on the date that any one person, or more than one person acting in concert (as defined in the City Code on Takeovers and Mergers), acquires ownership of shares in the capital of Valaris plc (the “Shares”) that, together with Shares held by such person or persons acting in concert, constitutes more than fifty percent (50%) of the total voting power of the Shares; or (b) the majority of the members of the Board is replaced during any twelve (12) month period by directors whose appointment or





election is not endorsed by a majority of the members of the Board prior to the date of the appointment or election; or (c) a sale of all or substantially all of the assets of Valaris plc; provided, however, a Change in Control of Valaris plc shall not be deemed to have occurred by virtue of the consummation of any transaction or series of related transactions immediately following which the beneficial holders of the voting Shares immediately before such transaction or series of transactions continue to have a majority of the direct or indirect ownership in one or more entities which, singly or together, immediately following such transaction or series of transactions, either (i) own all or substantially all of the assets of Valaris plc as constituted immediately prior to such transaction or series of transactions, or (ii) are the ultimate parent with direct or indirect ownership of all of the voting Shares after such transaction or series of transactions. For further clarification, a “Change in Control” of Valaris plc shall not be deemed to have occurred by virtue of the consummation of any transaction or series of related transactions effected for the purpose of changing the place of incorporation or form of organization of Valaris plc or the ultimate parent company of Valaris plc and its subsidiaries.
1.7    COBRA means the Consolidated Omnibus Budget Reconciliation Act of 1985, as amended together with the regulations and other official guidance promulgated thereunder.
1.8    Code means the United States Internal Revenue Code of 1986, as amended, and the treasury regulations and other official guidance promulgated thereunder.
1.9    Code Section 409Ameans Section 409A of the Code together with the treasury regulations and other official guidance promulgated thereunder.
1.10    Company means Ensco Incorporated, a Delaware corporation and any of its successors as provided in Article VI hereof.
1.11    Compensation Committee means the Compensation Committee of the Board.
1.12    Dependents means the Participant’s spouse and other dependents covered under the Employer’s medical, dental and vision plans immediately before the Participant’s termination date.
1.13    Disability shall occur upon the Participant becoming eligible for disability benefits under the Employer’s long-term disability plan, or, if earlier, upon the Participant becoming eligible for Social Security disability benefits or any comparable state-provided disability benefits for Participants located in non-United States jurisdictions.
1.14    Effective Date means 10 November 2019, the effective date of Board approval of this Plan.
1.15    Eligible Individualmeans an employee of the Employer employed in one of the positions specified on Appendix A-1, or any other appendices as adopted and approved by the Committee from time to time, excluding any employee with an individual employment agreement or any other written agreement with the Employer, in either case, that provides for severance payments or benefits outside the context of a Change in Control. Eligible Individuals shall be limited to a select group or management or highly compensated employees of the Employer.
1.16    Employer means the Company and its Affiliates. For purposes of determining the entity responsible for making payments hereunder to a Participant, “Employer” shall mean the legal entity on whose payroll records the Participant is listed.
1.17    Exchange Actmeans the Securities Exchange Act of 1934, as amended together with regulations and other official guidance promulgated thereunder.





1.18    Participant means an Eligible Individual who is approved by the Compensation Committee (or an authorized delegate thereof) to participate in the Plan. An Eligible Individual shall become a Participant in the Plan as of the later of (i) the date he or she commences employment with the Employer, and (ii) the date he or she is approved by the Compensation Committee (or an authorized delegate thereof) to participate in the Plan.
1.19    Plan means this Valaris Executive Severance Plan, as amended from time to time in accordance with the terms and conditions hereof.
1.20    “Releaseshall have the meaning set forth in Section 2.2 hereof.
1.21    Severance Benefitsmeans the severance payments and benefits specified for a Participant in Appendix A-1 or any other appendices as adopted for any Participant by the Committee from time to time.
1.24    Target Bonusmeans a Participant’s annual target bonus opportunity under the Ensco plc 2018 Cash Incentive Plan, as amended from time to time, or any other annual cash incentive program maintained by the Employer.
ARTICLE II
SEVERANCE BENEFITS
2.1    Eligibility for Severance Benefits.
(a)Qualifying Events. If a Participant’s employment is terminated by the Employer without Cause (excluding by reason of death or Disability), then the Employer shall pay or provide the Participant with the Severance Benefits in accordance with Section 2.3 hereto, subject to the provisions of this Plan, including Section 2.2 hereof.
(b)Non-Qualifying Events. Unless otherwise provided by the Compensation Committee at the time of such a termination, a Participant shall not be entitled to the Severance Benefits if the Participant’s employment is terminated (i) by the Employer for Cause, (ii) by the Participant for any reason, (iii) on account of the Participant’s death or Disability, or (iv) for any reason other than as expressly specified in Section 2.1(a) hereof.
(c)No Duty to Mitigate; Offset; Set-off. No Participant entitled to receive Severance Benefits hereunder shall be required to seek other employment or to attempt in any way to reduce any amount payable to the Participant by the Employer pursuant to the Plan and there shall be no offset against any amounts due to the Participant under the Plan on account of any remuneration attributable to any subsequent employment that the Participant may obtain or otherwise. Except as set forth below, the amounts payable hereunder shall not be subject to setoff, counterclaim, recoupment, defense or other right which the Employer may have against the Participant. Notwithstanding the foregoing, to the extent that a Participant is entitled to severance payments or benefits from the Employer under any other severance policy, plan, program or agreement, including under applicable local legal requirements, the Ensco Incorporated Severance Plan (Shore-Based Employees), the Rowan Companies Plc Protection Plan, or any Change in Control Severance Agreement entered into with the Company or any of its Affiliates, each of the Severance Benefits payable under this Plan shall be reduced (but not below zero) by an amount equal to the comparable payments or benefits provided under such other policy, plan, program or agreement. In the event of the Participant’s breach of any provision hereunder, including, without limitation, Section 2.2 hereof or any provision of the Release, the Company shall be entitled to recover any payments previously made to the Participant hereunder





(including the value of any equity awards accelerated, valued by reference to the fair market value of a share of applicable stock on the date of acceleration).
2.2    Release Required. As a condition to receiving the Severance Benefits, the Participant must execute and not revoke a separation and release agreement in substantially the form attached hereto as Appendix B, with such changes thereto as the Company determines are appropriate to comply with local law or custom or any changes in legal requirements or best practices after the Effective Date (the “Release”). The Release must be executed and delivered to the Company within the period of time set forth therein.
2.3    Plan Benefits.
(d)Accrued Obligations. In the event of a Participant’s termination of employment for any reason, such Participant shall be entitled to receive the Accrued Obligations. Participation in all benefit plans of the Employer will terminate upon a Participant’s date of termination except as otherwise specifically provided in the applicable plan.
(e)Severance Benefits. The Severance Benefits for a Participant shall be determined as set forth in Appendix A-1 or Appendix A-2, attached hereto, as applicable, or as set forth in any other applicable appendices as adopted by the Committee for such Participant from time to time.
ARTICLE III
UNFUNDED PLAN
The Plan shall be “unfunded” and the Severance Benefits shall be paid out of the general assets of the Employer as and when the Severance Benefits become payable under the Plan. All Participants shall be solely unsecured general creditors of the Employer. If the Employer decides in its sole discretion to establish any advance accrued reserve on its books against the future expense of the Severance Benefits payable hereunder, or if the Employer decides in its sole discretion to fund a trust from which Plan benefits may be paid from time to time, such reserve or trust shall not under any circumstances be deemed to be an asset of the Plan.
ARTICLE IV
ADMINISTRATION OF THE PLAN
4.1    The Compensation Committee (or, where applicable, any duly authorized delegee of the Compensation Committee) shall have the exclusive right, power, and authority, in its sole and absolute discretion, to administer, apply and interpret the Plan and any other documents related thereto in good faith, and to decide all factual and legal matters arising in connection with the operation or administration of the Plan. Without limiting the generality of the foregoing, the Compensation Committee (or, where applicable, any duly authorized delegee of the Compensation Committee) shall have the sole and absolute discretionary authority to:
(a)    take all actions and make all decisions (including factual decisions) with respect to the eligibility for and the amount of benefits payable under the Plan;
(b)    formulate, interpret and apply rules, regulations and policies necessary to administer the Plan;
(c)    decide questions, including legal or factual questions, relating to the calculation and payment of benefits, and all other determinations made, under the Plan;





(d)    resolve and/or clarify in good faith any factual or other ambiguities, inconsistencies and omissions arising under the Plan or other Plan documents; and
(e)    process, and approve or deny, benefit claims and rule on any benefit exclusions.
All determinations made by the Compensation Committee (or, where applicable, any duly authorized delegee of the Compensation Committee) with respect to any matter arising under the Plan shall be final and binding on the Employer, the Participant, any beneficiary, and all other parties affected thereby.
4.2    Subject to the limitations of applicable law, the Compensation Committee may delegate any and all of its powers and responsibilities hereunder to other persons by formal resolution adopted by the Compensation Committee. Any such delegation shall not be effective until it is adopted by the Compensation Committee and accepted by the person(s) designated and may be rescinded at any time by written notice from the Compensation Committee to the person to whom the delegation is made. The Company’s Chief Executive Officer and Vice President, Human Resources are each hereby delegated the day-to-day authority to enter into Releases under the Plan and process the payment of benefits under the Plan.
ARTICLE V
AMENDMENT AND TERMINATION
The Board may amend, modify or terminate this Plan without notice, at any time and for any reason, except as prohibited by law; provided, however, that no such amendment, modification or termination may (a) materially and adversely affect the benefits or protections provided hereunder to any Participant who has incurred a termination by the Employer without Cause (excluding by reason of death or Disability) prior to the date of such amendment, modification or termination, or (b) for a period of twelve (12) months following the consummation of a Change in Control, without a Participant’s written consent, (i) prevent that Participant from becoming eligible for Severance Benefits under the Plan, or (ii) reduce or alter to the detriment of the Participant the Severance Benefits payable, or potentially payable, to the Participant under the Plan (including, without limitation, imposing additional conditions on payment or changes to the time or form of payment).
ARTICLE VI
SUCCESSORS
For purposes of the Plan, the Company shall include any and all successors or assignees, whether direct or indirect, by purchase, merger, consolidation or otherwise, to all or substantially all of the business or assets of the Company and such successors and assignees shall perform the Company’s obligations under the Plan, in the same manner and to the same extent that the Company would be required to perform such obligations if no such succession or assignment had taken place. In the event that the surviving corporation in any transaction to which the Company is a party is a subsidiary of another corporation, the ultimate parent corporation of such surviving corporation shall cause the surviving corporation to perform the obligations of the Company under the Plan in the same manner and to the same extent that the Company would be required to perform such obligations if no such succession or assignment had taken place. In such event, the term “Company,” as used in the Plan, shall mean the Company, as hereinbefore defined, and any successor or assignee (including the ultimate parent corporation) to the business or assets thereof which by reason hereof becomes bound by the terms and provisions of the Plan.





ARTICLE VII
MISCELLANEOUS
7.1    Minors and Incompetents. If the Compensation Committee shall find that any person to whom Severance Benefits are payable under the Plan is unable to care for his or her affairs because of illness or accident, or is a minor, any Severance Benefits due (unless a prior claim therefore shall have been made by a duly appointed guardian, committee or other legal representative) may be paid to the spouse, a child, parent, or brother or sister, or to any person deemed by the Compensation Committee to have incurred expense for such person otherwise entitled to Severance Benefits, in such manner and proportions as the Compensation Committee may determine in its sole discretion. Any such payment of Severance Benefits shall be a complete discharge of the liabilities of the Company, the Employer and the Compensation Committee under the Plan.
7.2    Limitation of Rights. Nothing contained herein shall be construed as conferring upon a Participant the right to continue in the employ of the Employer as an employee or in any other capacity or to interfere with the Employer’s right to discharge such Participant at any time for any reason whatsoever.
7.3    Payment Not Salary. Any Severance Benefits payable under the Plan shall not be deemed salary or other compensation to the Participant for the purposes of computing benefits to which the Participant may be entitled under any retirement plan or other arrangement of the Employer maintained for the benefit of its employees, unless such plan or arrangement provides otherwise.
7.4    Severability. In case any provision of the Plan shall be illegal or invalid for any reason, said illegality or invalidity shall not affect the remaining parts hereof, but the Plan shall be construed and enforced as if such illegal and invalid provision never existed.
7.5    Withholding. The Employer shall have the right to make such provisions as it deems necessary or appropriate to satisfy any obligation it may have to withhold federal, state or local income, payroll, national insurance or other taxes incurred by reason of payments pursuant to the Plan. In lieu thereof, to the extent permitted by applicable law, the Company and/or the Employer shall have the right to withhold the amounts of such taxes from any other sums due or to become due from the Company and/or the Employer to the Participant upon such terms and conditions as the Compensation Committee may prescribe.
7.6    Non-Alienation of Benefits. The Severance Benefits payable under the Plan shall not be subject to alienation, transfer, assignment, garnishment, execution or levy of any kind, and any attempt to cause any Severance Benefit to be so subjected shall not be recognized.
7.7    Governing Law. The Plan shall be governed by the laws of the State of Texas, without regard to the conflicts of law principles thereof.
7.8    Code Section 409A. The provisions of this Section 7.8 shall only apply if and to the extent that the applicable Participant is subject to the provisions of Code Section 409A. The intent of the parties is that payments and benefits under this Plan comply with or be exempt from Code Section 409A and, accordingly, to the maximum extent permitted, this Plan shall be interpreted to be in compliance therewith. If the Participant notifies the Company (with specificity as to the reason therefor) that the Participant believes that any provision of this Plan (or of any award of compensation, including equity compensation or benefits) would cause the Participant to incur any additional tax or interest under Code Section 409A and the Company concurs with such belief or the Company (without any obligation whatsoever to do so) independently makes such determination, the Company shall, after consulting with the Participant, reform such provision to attempt to comply with Code Section 409A through good faith modifications to the minimum extent reasonably appropriate to conform with Code Section 409A. To the extent that any provision hereof is modified in order





to comply with Code Section 409A, such modification shall be made in good faith and shall, to the maximum extent reasonably possible, maintain the original intent and economic benefit to the Participant and the Company of the applicable provision without violating the provisions of Code Section 409A. In no event whatsoever shall the Company be liable for any additional tax, interest or penalty that may be imposed on the Participant by Code Section 409A or damages for failing to comply with Code Section 409A. With respect to any payment or benefit considered to be nonqualified deferred compensation under Code Section 409A, a termination of employment shall not be deemed to have occurred for purposes of any provision of this Plan providing for the payment of any amounts or benefits upon or following a termination of employment unless such termination is also a “separation from service” within the meaning of Code Section 409A and, for purposes of any such provision of this Plan, references to a “termination,” “termination of employment” or like terms shall mean “separation from service.” Notwithstanding anything to the contrary in this Plan, if the Participant is deemed on the date of termination to be a “specified employee” within the meaning of that term under Code Section 409A(a)(2)(B), then with regard to any payment or the provision of any benefit that is considered nonqualified deferred compensation under Code Section 409A payable on account of a “separation from service,” such payment or benefit shall not be made or provided until the date which is the earlier of (i) the expiration of the six month period measured from the date of such “separation from service” of the Participant, and (ii) the date of the Participant’s death, to the extent required under Code Section 409A. Upon the expiration of the foregoing delay period, all payments and benefits delayed pursuant to this Section 7.8 (whether they would have otherwise been payable in a single sum or in installments in the absence of such delay) shall be paid or reimbursed to the Participant, without interest, in a lump sum, and any remaining payments and benefits due under this Plan shall be paid or provided in accordance with the normal payment dates specified for them herein. To the extent that reimbursements or other in-kind benefits under this Plan constitute “nonqualified deferred compensation” for purposes of Code Section 409A, (x) all expenses or other reimbursements hereunder shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by the Participant, (y) any right to reimbursement or in-kind benefits shall not be subject to liquidation or exchange for another benefit, and (z) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year. For purposes of Code Section 409A, the Participant’s right to receive any installment payments pursuant to this Plan shall be treated as a right to receive a series of separate and distinct payments. Whenever a payment under this Plan specifies a payment period with reference to a number of days, the actual date of payment within the specified period shall be within the sole discretion of the Company. Notwithstanding any other provision of this Plan to the contrary, in no event shall any payment under this Plan that constitutes “nonqualified deferred compensation” for purposes of Code Section 409A be subject to offset by any other amount unless otherwise permitted by Code Section 409A. Where payments under this Plan are to be made within a specified period after the Release becomes effective and irrevocable, and such period for the Participant’s consideration, execution and revocation of the Release spans two taxable years, payment shall be made in later taxable year.
7.9    Parachute Payment Limitations.
(a)    Notwithstanding any contrary provision in this Plan, if an Eligible Individual is a “disqualified individual” (as defined in Section 280G of the Code), and the Severance Benefits that would otherwise be paid to such Eligible Individual under this Plan together with any other payments or benefits that such Eligible Individual has a right to receive from the Company (and affiliated entities required to be aggregated in accordance with Q/A-10 and Q/A-46 of Treas. Reg. §1.280G-1) (collectively, the “Payments”) would constitute a “parachute payment” (as defined in Section 280G of the Code), the Payments shall be either (a) reduced (but not below zero) so that the aggregate present value of such Payments and benefits received by the Eligible Individual from the Company and its Affiliates shall be $1.00 less than three times





such Eligible Individual’s “base amount” (as defined in Section 280G of the Code) (the “Safe Harbor Amount”) and so that no portion of such Payments received by such Eligible Individual shall be subject to the excise tax imposed by Section 4999; or (b) paid in full, whichever produces the better net after-tax result for such Eligible Individual (taking into account any applicable excise tax under Section 4999 and any applicable federal, state and local income and employment taxes). The determination as to whether any such reduction in the amount of the Payments is necessary shall be made by the Company in good faith and such determination shall be conclusive and binding on such Eligible Individual. If reduced Payments are made to the Eligible Individual pursuant to this Section 7.9 and through error or otherwise those Payments exceed the Safe Harbor Amount, the Eligible Individual shall immediately repay such excess to the Company or its applicable Affiliate upon notification that an overpayment has been made.
(b)    The reduction of Payments, if applicable, shall be made by reducing, first, Severance Benefits to be paid in cash hereunder in the order in which such payments would be paid or provided (beginning with such payment or benefit that would be made last in time and continuing, to the extent necessary, through to such payment or benefit that would be made first in time) and second, by reducing any other cash payments that would be payable to the Eligible Individual outside of this Plan which are valued in full for purposes of Code Section 280G in a similar order (last to first), any third, by reducing any equity acceleration hereunder of awards which are valued in full for purposes of Section 280G of the Code in a similar order (last to first), and finally, by reducing any other payments or benefit provided hereunder in a similar order (last to first).
7.10    Non-Exclusivity. The adoption of the Plan by the Company shall not be construed as creating any limitations on the power of the Company to adopt such other supplemental severance arrangements as it deems desirable, and such arrangements may be either generally applicable or limited in application. Nothing in this Plan shall prevent or limit the Participant’s continuing or future participation in any benefit, bonus, incentive or other plan or program provided by the Company of any of its Affiliates and for which the Participant may qualify, nor shall anything herein limit or reduce such rights as the Participant may have under any agreements with the Company or any of its Affiliates; provided, that no payments or benefits under the Plan shall result in a duplication of payments or benefits provided under any severance plan or arrangement to which the Participant is eligible to participate or a party to. Amounts which are vested benefits or which the Participant is otherwise entitled to receive under any plan, policy, practice or program of or any contract or agreement with the Company or any of its Affiliates at or subsequent to the date of termination shall be payable in accordance with such plan, policy, practice or program or contract or agreement, except as explicitly modified by this Plan.
7.11    Headings and Captions; Number. The headings and captions herein are provided for reference and convenience only. They shall not be considered part of the Plan and shall not be employed in the construction of the Plan. Whenever used in the Plan, the singular shall be deemed to include the plural, unless the context clearly indicates otherwise.
7.12    Communications. All announcements, notices and other communications regarding the Plan will be made by the Company in writing (whether in electronic form or otherwise). Except for written amendments to the Plan or official written communications issued by the Company in connection with the Plan, Participants in the Plan may not rely on any representation or statement made by the Employer or any of its officers, directors, employees or agents, whether written or oral, regarding such Participants’ participation in the Plan and any rights hereunder.
7.13    Notices. For purposes of this Plan, notices and all other communications provided for in this Plan or contemplated hereby shall be in writing and shall be deemed to have been duly given when personally delivered, delivered by a nationally recognized overnight delivery service or when mailed via United States





certified or registered mail, return receipt requested, postage prepaid, and addressed, in the case of the Company, to the Company at:
Valaris plc
Attn: General Counsel
5847 San Felipe, Suite 3300
Houston, TX 77057
and in the case of the Participant, to the Participant at the most recent address of the Participant that is set forth in the Company’s records.
7.14    Local Legal Requirements. The Company’s Chief Executive Officer and Vice President, Human Resources may create sub-plans that revise the terms of this Plan, including the Release attached hereto as Exhibit B, as each such individual deems advisable or appropriate to conform to or comply with any applicable foreign or local legal requirements or customs. Such sub-plans shall be applied consistently to all similarly-situated Participants located in the effected jurisdiction and shall not have the effect of increasing the amount of any Severance Benefits payable or to be provided hereunder.





Appendix A-1
Severance Benefits for Executive Vice Presidents

1.Cash Severance.
(a)If a Participant incurs a qualifying termination on or prior to April 4, 2020, an amount of cash, payable by the Employer in a lump sum promptly and in all events within 30 days following the date on which the Release as required by Section 2.2 becomes effective and irrevocable, equal to 2.00 multiplied by the sum of (i) the Participant’s Base Pay plus (ii) the Participant’s Target Bonus.
(b)If a Participant incurs a qualifying termination on or following April 5, 2020, an amount of cash, payable by the Employer in a lump sum promptly and in all events within 30 days following the date on which the Release as required by Section 2.2 becomes effective and irrevocable, equal to 1.50 multiplied by the Participant’s Base Pay.
2.Pro-Rata Annual Bonus.
A cash amount, equal to the product of (1) the Participant’s earned bonus for the year in which the termination occurs (based on actual results) under the Ensco Cash Incentive Plan (or such other Employer annual cash incentive plan in which the Participant participates immediately prior to the Participant’s termination of employment) multiplied by (2) a fraction, the numerator of which is that number of days Participant was employed by the Employer during the year of termination and the denominator of which is 365, payable by the Employer at the same time that annual bonus amounts for such year are paid to other Company executives and in all events by no later than March 15th of the calendar year following the year in which the termination of employment occurs.
3.LTIP Awards.
(a)Time-Based Awards. Any outstanding time-based equity awards (including cash settleable awards) granted prior to the Effective Date held by the Participant as of the date of termination shall be treated as set forth in the applicable plan and award agreement. Any outstanding unvested time-based equity awards (including cash settleable awards) granted on or following the Effective Date held by the Participant as of the date of termination shall 100% accelerate and become exercisable or settle (as applicable) within 30 days following the date on which the Release as required by Section 2.2 becomes effective and irrevocable.
(b)Performance-Based Awards. Any outstanding unvested performance-based equity awards (including cash settleable awards) granted prior to the Effective Date held by the Participant as of the date of termination shall be treated as set forth in the applicable plan and award agreement. A pro-rated portion of any outstanding unvested performance-based equity awards (including cash settleable awards) granted on or following the Effective Date held by the Participant as of the date of termination shall vest based on actual performance over the applicable performance period, with such pro-rated portion determined based on the number of full months of the Participant’s continuous service during the performance period out of the number of full months in the performance period. Vesting and settlement of such pro-rated awards shall not be accelerated and such awards shall remain subject to achievement of applicable performance criteria.





4.Other Benefits
(a)Subject to the Participant’s timely election of continuation coverage under COBRA or other applicable law, the Employer shall maintain continued group health plan coverage following the Participant’s termination date under any of the Employer’s medical, dental and vision plans that covered the Participant immediately before the Participant’s termination date, for the Participant and his or her eligible Dependents, for a period of twelve (12) months following the Participant’s termination date. During this period, the Participant shall be responsible for paying any contributions toward the cost of such coverages at active employee rates and the Employer shall (either directly or through reimbursement) subsidize the difference between such rates and any applicable premiums, whether under COBRA or otherwise. Following such 12-month period, the Participant shall be responsible for the full cost associated with any continued coverage, whether under COBRA, any insurance policy conversion rights or otherwise. The Employer’s obligation to provide subsidized continuation coverage under this Plan shall immediately terminate if the Participant becomes eligible for group medical coverage provided by another employer. The Participant shall give prompt notice to the Employer if he or she becomes eligible for group medical coverage offered by another employer during the 12-month period referenced in this section. In jurisdictions outside the United States, a health coverage benefit that is comparable to what is described in this Section 4(a) shall offered.
(b) The Participant shall receive Company-provided outplacement services for up to twelve (12) months following the Participant’s termination of employment.
(c)The Employer, at determined in its sole discretion in accordance with local customs, shall reimburse the Participant, up to a maximum aggregate amount of $1,500 or £1000, for any legal fees actually incurred by or on behalf of Participant in connection with the execution of the Release.





Appendix B
Form of Separation and Release Agreement
This Release Agreement (this “Release Agreement”) is entered into as of the date set forth below by and between [_____________], an individual (“Employee”), and [_____________] (the “Company”). Capitalized terms used herein that are not otherwise defined shall have the meaning ascribed to such terms in the Valaris Executive Severance Plan (the “Severance Plan”).  
WHEREAS, Employee has been employed by the Company as its [_____________];  
WHEREAS, Employee’s employment with the Company will terminate effective as of [_____________] (the “Termination Date”);
WHEREAS, Employee is eligible to receive severance payments and benefits (the “Severance Benefits”) in accordance with and subject to the terms of the Severance Plan; and
WHEREAS, Employee’s receipt of the Severance Benefits is subject to Employee’s execution and non-revocation of a release of claims, and the Company and Employee desire to enter into this Release Agreement upon the terms set forth herein. 
NOW, THEREFORE, in consideration of the covenants undertaken and the releases contained in this Release Agreement, and in consideration of the obligations of the Company to pay the Severance Benefits (conditioned upon this Release Agreement), Employee and the Company agree as follows:
1. Release. Employee, on behalf of herself, his or her descendants, dependents, heirs, executors, administrators, assigns, and successors, and each of them, hereby acknowledges full and complete satisfaction of the Company’s obligations to him or her and covenants not to sue and fully releases and discharges the Company and each of its direct and indirect parents, subsidiaries and affiliates, past and present, as well as its and their trustees, directors, officers, members, managers, partners, agents, attorneys, insurers, employees, stockholders, representatives, assigns, and successors, past and present, and each of them, hereinafter together and collectively referred to as the “Releasees,” with respect to and from any and all claims, wages, demands, rights, liens, agreements or contracts (written or oral), covenants, actions, suits, causes of action, obligations, debts, costs, expenses, attorneys’ fees, damages, judgments, orders and liabilities of whatever kind or nature in law, equity or otherwise (each, a “Claim”), which he or she now owns or holds or he or she has at any time heretofore owned or held or may in the future hold as against any of said Releasees arising out of or in any way connected with Employee’s service as an officer, director, employee, member or manager of any Releasee or Employee’s separation from his or her position as an officer, director, employee, manager and/or member, as applicable, of any Releasee, whether known or unknown, suspected or unsuspected, resulting from any act or omission by or on the part of said Releasees, or any of them, committed or omitted prior to the date of this Release Agreement including, without limiting the generality of the foregoing, any Claim under Title VII of the Civil Rights Act of 1964, the Age Discrimination in Employment Act of 1967 (“ADEA”), the Americans with Disabilities Act, the Family and Medical Leave Act of 1993, or any other federal, state or local law, regulation, or ordinance, or any Claim for severance pay, bonus, sick leave, holiday pay, vacation pay, life insurance, health or medical insurance or any other fringe benefit, workers’ compensation or disability; provided however, that the foregoing release shall not apply to any obligation of the Company to Employee pursuant to or with respect to any of the following: (1) any right to indemnification that Employee may have pursuant to the Company’s Bylaws or the Company’s corporate charter or under any written indemnification agreement with the Company (or any corresponding provision of any subsidiary or affiliate of the Company) with respect to any loss, damages or expenses (including but not limited to attorneys’ fees





to the extent otherwise provided) that Employee may in the future incur with respect to his or her service as an employee, officer or director of the Company or any of its subsidiaries or affiliates; (2) any rights that Employee may have to insurance coverage for such losses, damages or expenses under any Company (or subsidiary or affiliate) directors and officers liability insurance policy; (3) any rights to continued group health plan coverage that Employee may have under COBRA; or (4) any rights to payment of benefits that Employee may have under a retirement plan sponsored or maintained by the Company that is intended to qualify under Section 401(a) of the Internal Revenue Code of 1986, as amended. In addition, this release does not cover any Claim that cannot be so released as a matter of applicable law. Employee acknowledges and agrees that he or she has received any and all leave and other benefits that he or she has been and is entitled to pursuant to the Family and Medical Leave Act of 1993. 
2. Acknowledgment of Payment of Wages and Offset. Employee acknowledges that he or she has received all amounts owed for his or her regular and usual salary (including, but not limited to, any bonus or other wages), and usual benefits through the date of this Release Agreement. The Severance Benefits shall, however, be subject to setoff, counterclaim, recoupment, defense or other right which the Company may have against Employee and shall, to the extent permitted by applicable law, be reduced by the amount of any (i) severance pay or acceleration of benefits under any other agreement with, or plan, program, or policy of, the Company (if any) and (ii) other payments that the Company may otherwise be compelled to pay to Employee under applicable law (other than amounts owed for his or her regular and usual salary including, but not limited to, any bonus or other wages, and usual benefits through the Termination Date).  
3. ADEA Waiver. Employee expressly acknowledges and agrees that by entering into this Release Agreement, Employee is waiving any and all rights or Claims that he or she may have arising under ADEA and the Older Worker Benefits Protection Act (“OWBPA”), which have arisen on or before the date of execution of this Release Agreement. Employee further expressly acknowledges and agrees that: 
(A) Employee is hereby advised in writing by this Release Agreement to consult with an attorney before signing this Release Agreement; 
(B) Employee has voluntarily chosen to enter into this Release Agreement and has not been forced or pressured in any way to sign it; 
(C) Employee was given a copy of this Release Agreement on [_____________] and informed that he or she had [forty-five (45) / twenty-one (21)] days within which to consider this Release Agreement and that if he or she wished to execute this Release Agreement prior to expiration of such [45 / 21]-day period, he or she should execute the Endorsement attached hereto; 
(D) Employee was informed that he or she had seven (7) days following the date of execution of this Release Agreement in which to revoke this Release Agreement, and this Release Agreement will become null and void if Employee elects revocation during that time.  Any revocation must be in writing and must be received by the Company during the seven-day revocation period.  In the event that Employee exercises his or her right of revocation, neither the Company nor Employee will have any obligations under this Release Agreement;  
(E) Nothing in this Release Agreement prevents or precludes Employee from challenging or seeking a determination in good faith of the validity of this waiver under the ADEA or the OWBPA, nor does it impose any condition precedent, penalties or costs from doing so, unless specifically authorized by federal law. 





4. No Transferred Claims. Employee warrants and represents that the Employee has not heretofore assigned or transferred to any person not a party to this Release Agreement any released matter or any part or portion thereof and he or she shall defend, indemnify and hold the Company and each of its affiliates harmless from and against any claim (including the payment of attorneys’ fees and costs actually incurred whether or not litigation is commenced) based on or in connection with or arising out of any such assignment or transfer made, purported or claimed. 
5. Severability. It is the desire and intent of the parties hereto that the provisions of this Release Agreement be enforced to the fullest extent permissible under the laws and public policies applied in each jurisdiction in which enforcement is sought.  Accordingly, if any particular provision of this Release Agreement shall be adjudicated by a court of competent jurisdiction to be invalid, prohibited or unenforceable under any present or future law, such provision, as to such jurisdiction, shall be ineffective, without invalidating the remaining provisions of this Release Agreement or affecting the validity or enforceability of such provision in any other jurisdiction; furthermore, in lieu of such invalid or unenforceable provision there will be added automatically as a part of this Release Agreement, a legal, valid and enforceable provision as similar in terms to such invalid or unenforceable provision as may be possible.  Notwithstanding the foregoing, if such provision could be more narrowly drawn so as not to be invalid, prohibited or unenforceable in such jurisdiction, it shall, as to such jurisdiction, be so narrowly drawn, without invalidating the remaining provisions of this Release Agreement or affecting the validity or enforceability of such provision in any other jurisdiction. 
6. Counterparts. This Release Agreement may be executed in separate counterparts, each of which is deemed to be an original and all of which taken together constitute one and the same agreement. 
7. Governing Law. THIS RELEASE AGREEMENT WILL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF TEXAS, WITHOUT GIVING EFFECT TO ANY CHOICE OF LAW OR CONFLICTING PROVISION OR RULE (WHETHER OF THE STATE OF TEXAS OR ANY OTHER JURISDICTION) THAT WOULD CAUSE THE LAWS OF ANY JURISDICTION OTHER THAN THE STATE OF TEXAS TO BE APPLIED. IN FURTHERANCE OF THE FOREGOING, THE INTERNAL LAW OF THE STATE OF TEXAS, WILL CONTROL THE INTERPRETATION AND CONSTRUCTION OF THIS RELEASE AGREEMENT, EVEN IF UNDER SUCH JURISDICTION’S CHOICE OF LAW OR CONFLICT OF LAW ANALYSIS, THE SUBSTANTIVE LAW OF SOME OTHER JURISDICTION WOULD ORDINARILY APPLY. 
8. Amendment and Waiver. The provisions of this Release Agreement may be amended and waived only with the prior written consent of the Company and Employee, and no course of conduct or failure or delay in enforcing the provisions of this Release Agreement shall be construed as a waiver of such provisions or affect the validity, binding effect or enforceability of this Release Agreement or any provision hereof. 
9. Descriptive Headings. The descriptive headings of this Release Agreement are inserted for convenience only and do not constitute a part of this Release Agreement. 
10. Construction. Where specific language is used to clarify by example a general statement contained herein, such specific language shall not be deemed to modify, limit or restrict in any manner the construction of the general statement to which it relates.  The language used in this Release Agreement shall be deemed to be the language chosen by the parties to express their mutual intent, and no rule of strict construction shall be applied against any party. 
11. Arbitration. Any disputes relating to this Release Agreement, including the arbitrability thereof, shall by mutual agreement be finally settled by binding arbitration in accordance with the Judicial Arbitration





& Mediation Service, Inc. (“JAMS”) Comprehensive Arbitration Rules and Procedures or any successor provision thereto, as follows: Any party aggrieved will deliver a notice to the other party setting forth the specific points in dispute. Any points remaining in dispute thirty (30) days after the giving of such notice may be submitted to JAMS arbitration conducted before a single neutral arbitrator in Houston, Texas. The arbitrator shall be appointed by agreement of the parties hereto or, if no agreement can be reached, by JAMS. The arbitrator may enter a default decision against any party who fails to participate in the arbitration proceedings. Notwithstanding the foregoing, a party who seeks equitable relief shall not be obligated to utilize the arbitration proceedings required hereunder and instead may seek such relief in any state or federal court sitting in Houston, Texas. The decision of the arbitrator on the points in dispute will be final, unappealable and binding, and judgment on the award may be entered in any court having jurisdiction thereof. The arbitrator shall only be authorized to interpret the provisions of this Release Agreement, and shall not amend, change or add to any such provisions. The parties agree that this provision has been adopted by the parties to rapidly and inexpensively resolve any disputes between them and that this provision will be grounds for dismissal of any court action commenced by either party with respect to this Release Agreement, other than post-arbitration actions seeking to enforce an arbitration award or proceedings seeking equitable relief as permitted by this Release Agreement. In the event that any court determines that this arbitration procedure is not binding, or otherwise allows any litigation regarding a dispute, claim, or controversy covered by this Release Agreement to proceed, the parties hereto hereby waive any and all right to a trial by jury in or with respect to such litigation. Each party will bear its own expenses and the fees of its own attorneys. The parties and the arbitrator will keep confidential, and will not disclose to any person, except the parties' advisors and legal representatives, or as may be required by law or to enforce in court an arbitrator's award, the existence of any dispute hereunder. Employee acknowledges that arbitration pursuant to this Release Agreement includes all controversies or claims of any kind (e.g., whether in contract or in tort, statutory or common law, legal or equitable) now existing or hereafter arising under any federal, state, local or foreign law, including, but not limited to, the ADEA, the OWBPA, Title VII of the Civil Rights Act of 1964, the Civil Rights Act of 1866, the Employee Retirement Income Security Act, the Family and Medical Leave Act of 1993, the Americans With Disabilities Act and all similar federal, state and local laws, and Employee hereby waives all rights thereunder to have a judicial tribunal and/or a jury determine such claims. 
12. Restrictive Covenants.
(A) Each party acknowledges and agrees that Employee shall continue to be obligated to comply with the terms of any restrictive covenant, intellectual property, or confidentiality agreement that Employee executed in connection with Employee’s employment with the Company or its affiliates.
(B) Confidentiality. During the course of Employee’s employment with the Company, the Company has (1) disclosed or entrusted to Employee, and provided Employee with access to, Confidential Information (as defined below), (2) placed Employee in a position to develop business goodwill belonging to Valaris, plc (“Valaris”) and its affiliates, and (3) disclosed or entrusted to Employee business opportunities to be developed for Valaris and its affiliates. Valaris and its affiliates have also taken such actions on the date of this Release Agreement. Employee acknowledges that Confidential Information has been developed or acquired by Valaris and its affiliates through the expenditure of substantial time, effort and money and provides Valaris and its affiliates with an advantage over competitors who do not know or use the Confidential Information. Employee further acknowledges and agrees that the nature of the Confidential Information obtained during his or her employment would make it difficult, if not impossible, for Employee to perform in a similar capacity for a business competitive with Valaris and its affiliates without disclosing or utilizing Confidential Information. Employee shall hold in confidence and not directly or indirectly disclose, use, copy or





make lists of any Confidential Information, except to the extent necessary to carry out his or her duties on behalf of Valaris and its affiliates. Employee agrees to give to Valaris and its affiliates notice of any and all attempts to compel disclosure of any Confidential Information within one (1) business day of being informed that such disclosure is being, or will be, compelled. Such written notice shall include a description of the Confidential Information to be disclosed, the court, government agency, or other forum through which the disclosure is sought, and the date by which the Confidential Information is to be disclosed, and shall contain a copy of the subpoena, order or other process used to compel disclosure. For the avoidance of doubt, the provisions of this subsection shall not apply to (a) any disclosure or use authorized by Valaris or its affiliates or required by applicable law and (b) any information that is or becomes generally available to the public (other than as a result of Employee’s unauthorized disclosure). This confidentiality covenant shall be in addition to, and not limit or restrict in any way, any other confidentiality agreement or other post-employment covenant between Employee and Valaris and its affiliates.
As used herein, “Confidential Information” means information (whether or not recorded in documentary form, or stored on any magnetic or optical disk or memory) relating to the business, products, affairs and finances of Valaris or any of its affiliates for the time being confidential to Valaris or its affiliates, and trade secrets including, without limitation, technical data and know-how relating to the business of Valaris or any of its affiliates or any of their respective business contacts, including in particular (by way of illustration only and without limitation): (i) information relating to the business of exploring, acquiring, developing, exploiting and disposing of oil and natural gas resources (regardless of when conceived, made, developed or acquired); (ii) information relating to the business or prospective business, current or projected plans or internal affairs of Valaris or any of its affiliates; (iii) information relating to the current or prospective marketing or sales of any products or services of Valaris or any of its affiliates, including non-public lists of customers' and suppliers' names, addresses and contacts; sales targets and statistics; market share and pricing information; marketing surveys; research and reports; non-public advertising and promotional material; strategies; and financial and sales data; (iv) information relating to any actual or prospective business strategies of Valaris or any of its affiliates; (v) information relating to any actual acquisitions, investments or corporate opportunities or prospective acquisition, investment targets or corporate opportunities; (vi) know-how, trade secrets, unpublished information relating to Valaris or any of its affiliates’ intellectual property and to the creation, production or supply of any products or services of Valaris or any of its affiliates; (vii) information to which Valaris or any of its affiliates owes an obligation of confidence to a third party (including, without limitation, customers, clients, suppliers, partners, joint venturers and professional advisors of Valaris or any of its affiliates); and (viii) other commercial, financial or technical information relating to the business or prospective business of Valaris or any of its affiliates, or to any past, current or prospective client, customer, supplier, licensee, officer or employee, agent of Valaris or any of its affiliates, or any member or person interested in the share capital or assets of Valaris or any of its affiliates, and any other person to whom Valaris or any of its affiliates may provide or from whom they may receive information (whether marked confidential or not).
(C)    Non-Compete. In exchange for the Severance Benefits and the Company’s provision to Employee of Confidential Information and to protect the Company and its affiliates’ legitimate business interests, Employee hereby agrees that for a period of [twelve (12) / six (6)] months after the Termination Date (the “Restricted Period”), Employee will not, without the prior written consent of the Chief Executive Officer of Valaris plc, directly or indirectly, provide services to, or own any interest in, manage, operate, control, or participate in the ownership, management, operation or control of, any Direct Competitor (including as an employee or consultant, other than as an employee of, or consultant to, the Company or its affiliates); provided, however, that notwithstanding the foregoing,





Employee may own, directly or indirectly, solely as a passive investment, securities of any entity traded on a national securities exchange if Employee is not a controlling person of, or a member of a group which controls, such entity and does not, directly or indirectly, own two percent (2%) or more of any class of securities of such entity.
(D)    Non-Solicitation. Employee hereby agrees that during the Restricted Period Employee will not, directly or indirectly, induce or attempt to induce, or cause or solicit any officer, manager, contractor or employee of the Company or its Affiliates to cease their relationship with the Company or its Affiliates or hire or engage any such officer, manager, contractor or employee of the Company or its Affiliates, or in any way materially interfere with the relationship between the Company and its Affiliates, on the one hand, and any such officer, manager, contractor or employee, on the other hand. Notwithstanding the foregoing, nothing in this Release Agreement shall prohibit Employee from making a general, public solicitation for employment, or using an employee recruiting or search firm to conduct a search, that does not specifically target employees or consultants of the Company or its Affiliates so long as no persons who were at any time during the twelve (12) month period prior to the commencement of such solicitation, employees or consultants of the Company or its Affiliates are hired or otherwise engaged as a result of such general solicitations or search firm efforts. Employee hereby agrees that during the Restricted Period, he will not, directly or indirectly, induce, or attempt to induce, cause or solicit any customer, client or supplier of the Company or its Affiliates to reduce or cease doing business with the Company or its Affiliates, or in any way knowingly interfere with the relationship between any customer, client or supplier of the Company or its Affiliates, on the one hand, and the Company and its Affiliates, on the other hand.
(E)    Intellectual Property Assignment. Employee hereby assigns to the Company all rights, including, without limitation, copyrights, patents, trade secret rights, and other intellectual property rights associated with any ideas, concepts, techniques, inventions, processes, works of authorship, Confidential Information or trade secrets (i) developed or created by Employee, solely or jointly with others, during the course of performing work for or on behalf of the Company or any of its Affiliates at any time during Employee’s period of employment with the Company, (ii) that Employee conceived, developed, discovered or made in whole or in part during Employee’s employment by the Company that relate to the business of the Company or its Affiliates or the actual or demonstrably anticipated research or development of the Company or its Affiliates, or (iii) that Employee conceives, develops, discovers or makes in whole or in part during or after Employee’s employment by the Company that are made through the use of any trade secrets of the Company or the use of the equipment, facilities, supplies, or time of the Company or its Affiliates (collectively, “Work Product”). Without limiting the foregoing, to the extent possible, all software, compilations and other original works of authorship included in the Work Product will be considered a “work made for hire” as that term is defined in Title 17 of the United States Code. If, notwithstanding the foregoing, Employee for any reason retains any right, title or interest in or relating to any Work Product, Employee agrees promptly to assign, in writing and without any requirement of further consideration, all such right, title, and interest to the Company. Upon request of the Company at any time, Employee will take such further actions, including execution and delivery of instruments of conveyance, as may be appropriate to evidence, perfect, record or otherwise give full and proper effect to any assignments of rights under or pursuant to this Release Agreement.
(F)    Company Documents and Property. All writings, records, and other documents and things comprising, containing, describing, discussing, explaining, or evidencing any Confidential Information, and all equipment, computers, mobile phones, components, manuals, parts, keys, tools, and the like in Employee’s custody, possession or control that have been obtained by, prepared by,





or provided to, Employee by the Company or any Affiliate in the course or scope of Employee’s employment with the Company (or any Affiliate) shall be the exclusive property of the Company (or such Affiliate, as applicable), shall not be copied and/or removed from the premises of the Company or any Affiliate, except in pursuit of the business of the Company or an Affiliate, and shall be delivered to the Company or an Affiliate, as applicable, without Employee retaining any copies or electronic versions, within one (1) day following the Termination Date or at any other time requested by the Company.
(G)    No Disparaging Comments. Employee and the Company shall refrain from any criticisms or disparaging comments about each other or in any way relating to Employee’s employment or separation from employment with the Company; provided, however, that nothing in this Release Agreement shall apply to or restrict in any way the communication of information to any governmental law enforcement agency by either Party that is required by compulsion of law. A violation or threatened violation of this prohibition may be enjoined by a court of competent jurisdiction. The rights under this provision are in addition to any and all rights and remedies otherwise afforded by law to the Parties. Employee acknowledges that in executing this Release Agreement, he or she has knowingly, voluntarily, and intelligently waived any free speech, free association, free press or First Amendment to the United States Constitution (including, without limitation, any counterpart or similar provision or right under any other state constitution which may be deemed to apply) and rights to disclose, communicate, or publish disparaging information or comments concerning or related to the Company; provided, however, nothing in this Release Agreement shall be deemed to prevent Employee from testifying fully and truthfully in response to a subpoena from any court or from responding to an investigative inquiry from any governmental agency. For all purposes of the obligations of Employee under this Section 12(G), the term “Company” refers to the Company and its Affiliates, and its and their directors, officers, employees, shareholders, investors, partners and agents.
(H)    Cooperation. Employee agrees to make himself or herself available as reasonably practical with respect to, and to use reasonable efforts to cooperate in conjunction with, the transition of duties and any litigation or investigation arising from events that occurred during Employee’s employment with or engagement by the Company (whether such litigation or investigation is then pending or subsequently initiated) involving the Company or any affiliate thereof, including providing testimony and preparing to provide testimony if so requested by the Company.
(I)    Employee also agrees to keep confidential the terms of this Release Agreement. This provision does not prohibit Employee from providing this information on a confidential and privileged basis to his or her attorneys or accountants for purposes of obtaining legal or tax advice or as otherwise required by law. Moreover, the parties have the right to disclose in confidence trade secrets to government officials, or to an attorney, for the sole purpose of reporting or investigating a suspected violation of law. The parties also have the right to disclose trade secrets in a document filed in a lawsuit or other proceeding, but only if the filing is made under seal and protected from public disclosure all in accordance with 18 U.S.C. § 1833(b). Nothing in this Release Agreement shall restrict such disclosures.
13. Nouns and Pronouns. Whenever the context may require, any pronouns used herein shall include the corresponding masculine, feminine or neuter forms, and the singular form of nouns and pronouns shall include the plural and vice-versa. 
14. Legal Counsel. Each party recognizes that this is a legally binding contract and acknowledges and agrees that they have had the opportunity to consult with legal counsel of their choice.  Employee acknowledges and agrees that he or she has read and understands this Release Agreement completely, is





entering into it freely and voluntarily, and has been advised to seek counsel prior to entering into this Release Agreement and he or she has had ample opportunity to do so.
15. Entire Agreement. The Severance Plan and this Release Agreement set forth the entire agreement of the parties and fully supersede and replace any and all prior agreements, promises, representations, or understandings, written or oral, between the Employer and Employee that relate to the subject matter of the Severance Plan and this Release Agreement. This Release Agreement may be amended or modified only by a written instrument identified as an amendment hereto that is executed by both parties.
This Release Agreement may not be executed prior to the Termination Date. The undersigned has read and understands the consequences of this Release Agreement and voluntarily signs it. The undersigned declares under penalty of perjury under the laws of the State of Texas that the foregoing is true and correct. 
     EXECUTED this ___ day of ___________________, 20______, at ________________. 
 
“Employee”
 
 
 
 
 
[_______________]
 
 
 
ENDORSEMENT 
I, [_______________], hereby acknowledge that I was given [45 / 21] days to consider the foregoing Release Agreement and voluntarily chose to sign the Release Agreement prior to the expiration of the [45 / 21]-day period. 
I declare under penalty of perjury under the laws of the United States and the State of Texas that the foregoing is true and correct. 
EXECUTED this ___ day of ___________________, 20______, at [_______________].
 
 
 
 
 
 
[_______________]






 
 
SUBSIDIARIES OF THE REGISTRANT
 
 
Valaris plc Subsidiaries as of December 31, 2019
 
 
Company Name
Jurisdiction
Alpha Achiever Company
Cayman Islands
Alpha Admiral Company
Cayman Islands
Alpha Archer Company
Cayman Islands
Alpha International Drilling Company S.à r.l. (in liquidation)
Luxembourg
Alpha Leasing Drilling Limited
Mauritius
Alpha Offshore Drilling (S) Pte. Ltd.
Singapore
Alpha Offshore Drilling Services Company
Cayman Islands
Alpha Offshore Drilling Services Company (Ghana) Limited
Ghana
Alpha Offshore International Leasing Limited
England and Wales
ATLANTIC MARITIME SERVICES LLC
Delaware
Atwood Advantage S.à r.l. (in liquidation)
Luxembourg
Atwood Australian Waters Drilling Pty Ltd
Western Australia
Atwood Beacon S.à r.l. (in liquidation)
Luxembourg
Atwood Deep Seas, Ltd.
Texas
Atwood Drilling, Inc.
Delaware
Atwood Hunter Co.
Delaware
Atwood Malta Holding Company Limited
Malta
Atwood Oceanics (M) Sdn. Bhd.
Malaysia
Atwood Oceanics Australia Pty. Limited
Western Australia
Atwood Oceanics Drilling Mexico, S. de R.L. de C.V.
Mexico
Atwood Oceanics Leasing Limited
Labuan FT
Atwood Oceanics Malta Limited
Malta
Atwood Oceanics Management, Inc.
Delaware
Atwood Oceanics Services Mexico, S. de R.L. de C.V.
Mexico
Atwood Oceanics, Inc.
Texas
Atwood Offshore (Gibraltar) Advantage Limited (in liquidation)
Gibraltar
Atwood Offshore (Gibraltar) Beacon Limited (in liquidation)
Gibraltar
Atwood Offshore (Gibraltar) Limited (in liquidation)
Gibraltar
Atwood Offshore Drilling Limited
Hong Kong
Aurora Offshore Services Gmbh
Germany
British American Offshore Limited
England and Wales
C.A. Foravep, Forasol Venezuela de Perforaciones
Venezuela
Clearways Offshore Drilling Sdn. Bhd.
Malaysia
Durand Maritime S.A.S. (In Liquidation)
France
ENSCO (Bermuda) Limited
Bermuda
Ensco (Myanmar) Limited
Republic of Myanmar
Ensco (Thailand) Limited
Thailand
ENSCO Arabia Co. Ltd.
Saudi Arabia
ENSCO Asia Company LLC
Texas
ENSCO Asia Pacific Pte. Limited
Singapore
ENSCO Australia Pty. Limited
Western Australia
ENSCO Capital Limited
Cayman Islands
ENSCO Corporate Resources LLC
Delaware
ENSCO de Venezuela, S.R.L.
Venezuela
Ensco Deepwater Drilling Limited
England and Wales
Ensco Deepwater USA II LLC
Delaware
ENSCO Development Limited
Cayman Islands
Ensco do Brasil Petróleo e Gás Ltda.
Brazil
ENSCO Drilling Company (Nigeria) Ltd.
Nigeria
ENSCO Drilling Company LLC
Delaware
ENSCO Drilling Mexico LLC
Delaware
Ensco Drilling Transnational Services Limited
Ghana





Ensco Endeavors Limited
Cayman Islands
Ensco France S.A.S.
France
ENSCO Gerudi (M) Sdn. Bhd.
Malaysia
ENSCO Global GmbH
Switzerland
Ensco Global II Ltd.
Cayman Islands
ENSCO Global Investments LP
England and Wales
ENSCO Global Limited
Cayman Islands
ENSCO Global Resources Limited
England and Wales
Ensco Holdco Limited
England and Wales
ENSCO Holding Company
Delaware
Ensco Holdings II Ltd.
Delaware
Ensco Holdings III Ltd.
Delaware
ENSCO Holland B.V.
Netherlands
Ensco Holland B.V. (Malta Branch)
Malta
ENSCO Incorporated
Texas
Ensco Intercontinental GmbH
Switzerland
ENSCO International Incorporated
Delaware
Ensco International Management GP LLC
Delaware
Ensco International Management LP LLC
Delaware
ENSCO Investments LLC
Nevada
ENSCO Labuan Limited
Labuan FT
Ensco Mexico Services, S. de R.L. de C.V.
Mexico
Ensco North America LLC
Delaware
ENSCO North America LLC (Israel Branch)
Israel
Ensco Ocean 1 Company
Cayman Islands
Ensco Ocean 2 Company
Cayman Islands
ENSCO Oceanics Company LLC
Delaware
ENSCO Offshore Company
Delaware
Ensco Offshore International LLC
Delaware
Ensco Offshore Petróleo e Gás Ltda.
Brazil
Ensco Offshore Services LLC
Delaware
ENSCO Offshore U.K. Limited
England and Wales
ENSCO Overseas Limited
Cayman Islands
Ensco Rowan Limited
England and Wales
ENSCO Services Limited
England and Wales
ENSCO Services LLC
Delaware
Ensco South Pacific LLC
Delaware
Ensco Transcontinental I LLC
Nevada
Ensco Transcontinental I LP
England and Wales
Ensco Transcontinental II LLC
Nevada
Ensco Transcontinental II LP
England and Wales
ENSCO U.K. Limited
England and Wales
Ensco UK Drilling Limited
England and Wales
ENSCO United Incorporated
Delaware
Ensco Universal Holdings I Ltd.
Cayman Islands
Ensco Universal Holdings II Ltd.
Cayman Islands
ENSCO Universal Limited
England and Wales
Ensco Vistas Limited
Cayman Islands
ENSCO Worldwide GmbH
Switzerland
ENSCO Worldwide Investments Limited
England and Wales
EnscoRowan Ghana Drilling Limited
Ghana
Foradel SDN B.H.D.
Malaysia
Forasub B.V.
Netherlands
Forinter Limited
Jersey
Great White Shark Limited
Gibraltar
Green Turtle Limited
Gibraltar
International Technical Services LLC
Delaware
Internationale de Travaux et de Materiel (I.T.M.) S.A.S.
France





Manatee Limited
Malta
Manta Ray Limited
Malta
Marine Blue Limited
Gibraltar
Ocean Deep Drilling ESV Nigeria Limited
Nigeria
Offshore Drilling Services LLC
Delaware
P.T. ENSCO Sarida Offshore
Indonesia
Petroleum International Pte. Ltd.
Singapore
Pride Arabia Co. Ltd.
Saudi Arabia
Pride Foramer S.A.S.
France
Pride Forasol Drilling Nigeria Ltd.
Nigeria
Pride Forasol S.A.S.
France
Pride Global II Ltd.
British Virgin Islands
Pride Global Offshore Nigeria Limited
Nigeria
Pride International LLC
Delaware
Pride International Management Company LP
Texas
PT Alpha Offshore Drilling
Indonesia
PT Pentawood Offshore Drilling
Indonesia
Ralph Coffman Limited
Gibraltar
Ralph Coffman Luxembourg S.à r.l.
Luxembourg
RD International Services Pte. Ltd.
Singapore
RDC Holdings Luxembourg S.à r.l.
Luxembourg
RDC Malta Limited
Malta
RDC Offshore Luxembourg S.à r.l.
Luxembourg
RDC Offshore Malta Limited
Malta
Rowan (UK) Relentless Limited
England and Wales
Rowan (UK) Reliance Limited
England and Wales
Rowan (UK) Renaissance Limited
England and Wales
Rowan (UK) Resolute Limited
England and Wales
Rowan 350 Slot Rigs, Inc.
Delaware
Rowan Angola Limitada
Angola
Rowan California S.à r.l.
Luxembourg
Rowan Companies Limited
England and Wales
Rowan Companies, Inc.
Delaware
Rowan Deepwater Drilling (Gibraltar) Limited
Gibraltar
Rowan Do Brasil Serviços De Perfuração Ltda.
Brazil
Rowan Drilling (Gibraltar) Limited
Gibraltar
Rowan Drilling (Trinidad) Limited
Trinidad
Rowan Drilling (U.K.) Limited
Scotland
Rowan Drilling Cyprus Limited
Cyprus
Rowan Drilling Services Limited
Gibraltar
Rowan Drilling Services Nigeria Limited
Nigeria
Rowan Drilling, S. De R.L. De C.V.
Mexico
Rowan Egypt Petroleum Services L.L.C.
Egypt
Rowan Finance LLC
Delaware
Rowan Financial Holdings S.à r.l.
Luxembourg
Rowan Finanz S.à r.l.
Luxembourg
Rowan Global Drilling Services Limited
Gibraltar
Rowan Gorilla V (Gibraltar) Limited
Gibraltar
Rowan Gorilla VII (Gibraltar) Limited
Gibraltar
Rowan Holdings Luxembourg S.à r.l.
Luxembourg
Rowan International Rig Holdings S.à r.l.
Luxembourg
Rowan Marine Services, Inc.
Texas
Rowan N-Class (Gibraltar) Limited
Gibraltar
Rowan No. 1 Limited
England and Wales
Rowan No. 2 Limited
England
Rowan Norway Limited (FKA Rowan (Gibraltar) Limited)
Gibraltar
Rowan Offshore (Gibraltar) Limited
Gibraltar
Rowan Offshore Luxembourg S.à r.l.
Luxembourg





Rowan Relentless Luxembourg S.à r.l.
Luxembourg
Rowan Reliance Luxembourg S.à r.l.
Luxembourg
Rowan Renaissance Luxembourg S.à r.l.
Luxembourg
Rowan Resolute Luxembourg S.à r.l.
Luxembourg
Rowan Rex Limited
Cayman Islands
Rowan Rigs S.à r.l.
Luxembourg
Rowan Services LLC
Delaware
Rowan Standard Ghana Limited
Ghana
Rowan UK Renaissance Onshore Limited
England and Wales
Rowan US Holdings (Gibraltar) Limited
Gibraltar
Rowan, S. de R.L. de C.V.
Mexico
Rowandrill Labuan Limited
Labuan
Rowandrill Malaysia Sdn. Bhd.
Malaysia
Rowandrill, Inc.
Texas
Saudi Aramco Rowan Offshore Drilling Company
Saudi Arabia
SKDP 1 Limited
Cyprus
SKDP 2 Limited
Cyprus
SKDP 3 Limited
Cyprus
Societe Maritime de Services "SOMASER" S.A.S.
France
Swiftdrill Malta
Malta






Consent of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders
Valaris plc:


We consent to the incorporation by reference in the registration statement (Nos. 333-230813, 333-174611, 333-58625, 033-40282, 333-97757, 333-125048, 333-156530, 333-181593, 333-204294, 333-211588, 333-218250, 333-220859 and 333-225151) on Form S-8 and (No. 333-221706) on Form S-3 of Valaris plc of our reports dated February 21, 2020, with respect to the consolidated balance sheets of Valaris plc and subsidiaries (the Company) as of December 31, 2019 and 2018, the related consolidated statements of operations, comprehensive loss, and cash flows for each of the years in the three-year period ending December 31, 2019, and the related notes, and the effectiveness of internal control over financial reporting as of December 31, 2019, which reports appear in the December 31, 2019 annual report on Form 10-K of Valaris plc.

Our report dated February 21, 2020 on the effectiveness of internal control over financial reporting as of December 31, 2019 contains an explanatory paragraph that states the Company acquired Rowan Companies plc during 2019, and management excluded from its assessment of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2019, Rowan Companies plc’s internal control over financial reporting associated with total revenues of $135.0 million and total expenses of $259.0 million included in the consolidated financial statements of the Company for the year ended December 31, 2019. Our audit of internal control over financial reporting of the Company also excluded an evaluation of the internal control over financial reporting of Rowan Companies plc.



/s/ KPMG LLP
Houston, Texas
February 21, 2020





Exhibit 31.1
 
CERTIFICATION
 
I, Tom P. Burke, certify that:
1.
I have reviewed this report on Form 10-K of Valaris plc;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
Dated:
February 21, 2020
 
/s/ Tom P. Burke
 
Tom P. Burke
President and Chief Executive Officer and Director




Exhibit 31.2
 
CERTIFICATION
 
I, Jonathan H. Baksht, certify that:
1.
I have reviewed this report on Form 10-K of Valaris plc;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
Dated:
February 21, 2020
 
/s/ Jonathan H. Baksht
 
Jonathan H. Baksht
Executive Vice President and Chief Financial Officer











Exhibit 32.1
 
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


In connection with the Annual Report of Valaris plc (the "Company") on Form 10-K for the period ending December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Tom P. Burke, President and Chief Executive Officer and Director of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1)   The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)   The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ Tom P. Burke
 
Tom P. Burke
President and Chief Executive Officer and Director
 
February 21, 2020
 






Exhibit 32.2
 
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


In connection with the Annual Report of Valaris plc (the "Company") on Form 10-K for the period ending December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Jonathan H. Baksht, Executive Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1)   The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)   The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ Jonathan H. Baksht
 
Jonathan H. Baksht
Executive Vice President and Chief Financial Officer
 
February 21, 2020